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Home My WebLink About200-023Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 2/04/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KTU 32-07 (PTD 200-023) PERF 01/23/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/07/2022 By Abby Bell at 3:53 pm, Feb 04, 2022 2SHUDWLRQV $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 3XOO7XELQJ 2SHUDWLRQVVKXWGRZQ 3HUIRUPHG 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH $OWHU&DVLQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HSDLU:HOO 5HHQWHU6XVS:HOO 2WKHUBBBBBBBBBBBBBBBBBBBBBB 'HYHORSPHQW ([SORUDWRU\ 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU:HOO1DPHDQG1XPEHU 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tĞůů͗<dhϯϮͲϬϳ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϭͬϮϬϭϲ W/͗ϱϬͲϭϯϯͲϮϬϰϵϭͲϬϬ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϯͲϯͬϴΗŽŶĚƵĐƚŽƌϲϭͬ<ͲϱϱͬEͬϭϮ͘ϱϭϱ^ƵƌĨĂĐĞϭϮϯΖ ϵͲϱͬϴΗ^ƵƌĨĂĐĞϰϬͬ>ͲϴϬͬEͬϴ͘ϴϯϱ^ƵƌĨĂĐĞϭ͕ϱϭϬΖ ϳΗ/ŶƚĞƌŵĞĚŝĂƚĞϮϯͬ>ͲϴϬͬEͬϲ͘ϯϲϲ^ƵƌĨĂĐĞϱ͕ϬϰϬΖ ϮϵͬWͲϭϭϬͬEͬϲ͘ϭϴϰϱ͕ϬϰϬΖϱ͕ϲϵϬΖ ϰͲϭͬϮΗ>ŝŶĞƌϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϮϭϯ͘ϵϱϴϱ͕ϱϰϬΖϵ͕ϭϭϳΖ dh/E'd/> ϰͲϭͬϮΗdƵďŝŶŐϭϮ͘ϲͬ>ͲϴϬͬEͬϯ͘ϵϱϴ^ƵƌĨĂĐĞϰ͕ϵϭϬ͛ :t>Zzd/> EŽĞƉƚŚ///ƚĞŵ ϭϰ͕ϴϬϯΖϯ͘ϴϯϯ͟ϱ͘ϴϳϱ͟ϰͲϭͬϮΗ'>DĂŶĚƌĞů͕<ͲϮ͕ŽƚƚŽŵ>ĂƚĐŚ;ŵǇ'>sϭϮͬϭϬͬϭϲͿ Ϯϰ͕ϴϲϮΖϯ͘ϴϭϯ͟ϱ͘ϬϯϬ͟yEŝƉƉůĞ ϯϰ͕ϴϴϭΖϯ͘ϵϱϴ͟ϱ͘ϮϬ͟ϰͲϭͬϮ͟ǆϳ͟dƌŝƉŽŝŶƚWĞƌŵWĂĐŬĞƌ ϰϰ͕ϵϬϬΖϯ͘ϴϭϯ͟ϯ͘ϴϭϯ͟yŶŝƉƉůĞ ϱϰ͕ϵϭϬ͛ϯ͘ϵϱϴ͟ϱ͘ϮϬ͟t>' ϲϱ͕ϱϰϬΖEͬEͬĂŬĞƌ&ůĞǆ>ŽŬ>ŝŶĞƌ,ĂŶŐĂƌǁͬyWWŬƌĂŶĚWZ ϳϳ͕ϮϳϬΖEͬEͬϰͲϭͬϮ͟/WĂƉƉĞĚǁŝƚŚϮϱ͛ĞŵĞŶƚʹƐĞƚϭϭͬϭϴͬϭϲ ϴϳ͕ϱϰϬ͛EͬEͬ/W ϵϳ͕ϱϵϲ͛EͬEͬ/WĂƉƉĞĚǁŝƚŚϮϱ͛ĞŵĞŶƚ ϭϬϵ͕ϬϱϬΖEͬEͬ,^'ƵŶ,ĂŶŐĂƌ ϭϭϵ͕ϬϳϰΖEͬEͬ,^ϭϬ<ƌŝůů WZ&KZd/KEd/> ŽŶĞdŽƉ ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&d^W&ĂƚĞ ^ƚĂƚƵƐ hͲyϰ͕ϵϴϵ͛ϰ͕ϵϵϱ͛ϰ͕ϲϳϭ͛ϰ͕ϲϳϳ͛ϲϲϬϭͬϭϮͬϭϳKƉĞŶ hͲϭϱ͕Ϭϯϰ͛ϱ͕Ϭϱϰ͛ϰ͕ϳϭϭ͛ϰ͕ϳϮϵ͛ϮϬϲϬϭͬϭϮͬϭϳKƉĞŶ hͲϭϱ͕Ϭϱϰ͛ϱ͕Ϭϳϰ͛ϰ͕ϳϮϵ͛ϰ͕ϳϰϳ͛ϮϬϲϬϭͬϮϬͬϭϳKƉĞŶ hͲϱϱ͕ϯϯϯ͛ϱ͕ϯϰϰ͛ϰ͕ϵϳϳ͛ϰ͕ϵϴϲ͛ϭϭϲϬϭͬϮϬͬϭϳKƉĞŶ 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ĂƐŝŶŐĞƚĂŝů ϵͲϱͬϴΗϭϮͲϭͬϰΗŚŽůĞǁͬϰϬϬƐŬƐŽĨĐĞŵĞŶƚ ϳ͟ϴͲϭͬϮ͟ŚŽůĞǁͬϰϰϱƐŬƐŽĨĐĞŵĞŶƚ ϰͲϭͬϮ͟ϲͲϭͬϴ͟ŚŽůĞǁͬϲϳϱƐŬƐŽĨĐĞŵĞŶƚ DĂǆ/ŶĐůŝŶĂƚŝŽŶ Ϯϴ͘ϳϰΣΛϮ͕ϳϳϭ͛ 2-0 0- 0'2--3 111 Seth Nolan Hilcorp Alaska, LLC 255 1]� , GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Te : 907 Ifilcnrla:11;i ka_HA; RECEIVED Fax 907 777-85010 E-mail: snolan@hilcorp.com MAR 092017 DATA LOGGED AOC 3!l3l201'7 DATE 03/08/2017 M. K. BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KTU 32-07 SCANNED APR 0 7 2U1Z Prints: Production Profile CD: Final Well Data DLIS Data 3/8/2017 4:05 PM File folder LAS Data 3/8/2017 4:05 PM File folder Log 3/8/2017 4:06 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: 2_0O- 2-3 • Z c6 D`-12 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 RECEIVED Fax: 907 777-8308 �•„ tt�iri,at:L:.k:�_Li.t: Fax: 907 777-8510 E-mail: snolan@hilcorp.com MAR 0 9 2017 DATA LOGGED DATE 03/07/2017 AOGCC 3AB NDER To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KTU 32-07 NCAA"E® APR 0 1 2017 Prints: Perforation Record CD: Final Well Data KTU_32-07_PERF_21DEC16.pdf 2/2/2017 1:32PM PDF Document 1,219 KB KTU_32-07_PERF_21DEC16 CORRELATION... 2/2/2017 1:41 PM LAS File 185 KB KTU_32-07PERF_21DEC 16 CORRELATION... 212/2017 1:41 PM LAS File 104 KB J KTU_32-07 PERF_21DEC 16 CORRELATION... 2/2/2017 1:41 PM LAS File 77 KB KTU_32-07_PERF_21DEC16_CORRELATION... 2/2/2017 1:41 PM LAS File 60 KB LJ KTU_32-07_PERF_21DEC 16_CORRELATION... 2/2/2017 1:41 PM LAS File 62 KB KTU_32-07_PERF_21DEC 16_img.tiff 2/2/20171:32 PM TIFF File 4,325 KB KTU_32-07 PERF_21DEC 16 PERFORATION... 2/2/20171:32 PM LAS File 47 KB KTU_32-07 PERF_21DEC 16 PERFORATION... 2/2/2017 1:32 PM LAS File 60 KB KTU_32-07 PERF_21DEC 16 PERFORATION... 2/2/2017 1:32 PM LAS File 54 KB KTU_32-07_PERF_21DEC 16 PERFORATION... 2/2120171:32 PM LAS File 43 KB KTU_32-07_PERF_21DEC 16_PERFORATION... 2/2/20171:32 PM LAS File 53 KB Thumbs.db 3/5/2017 12:14PM Data Base File 8 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: STATE OF ALASKA • RECEIVED AltKA OIL AND GAS CONSERVATION COMMISSION 4 �7 REPORT OF SUNDRY WELL OPERATIONS � � GCC 1.Operations Abandon U Plug Perforations LJ Fracture Stimulate U Pull Tubing 11 Aerations shutdown U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 2rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:N2 Jet/Displacement❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Exploratory DevelopmentEx ❑ p ry ❑ 200-023 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20491-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028142 Kenai Tyonek Unit 32-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field-Beluga/Upper Tyonek Gas Pool 11.Present Well Condition Summary: 7,270; Total Depth measured 9,117 feet Plugs measured 7,450;7,596 feet true vertical 8,648 feet Junk measured 9,022(fish) feet Effective Depth measured 9,047 feet Packer measured 4,881 &5,540 feet true vertical 8,578 feet true vertical 4,576&5,160 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 123' 13-3/8" 123' 123' 3,090 psi 1,540 psi Surface 1,510' 9-5/8" 1,510' 1,509' 5,750 psi 3,090 psi Intermediate 5,040' 7" 5,040' 4,717' 6,340 psi 3,830 psi Intermediate 650' 7" 5,690' 5,294' 11,220 psi 8,530 psi Liner 3,577' 4-1/2" 9,117' 8,548' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic : : scONED f A U 2.J► . Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 4,910'MD 4,601'ND Packers and SSSV(type,measured and true vertical depth) Perm Pkr&ZXP Pkr;N/A 4,88175,540'MD 4,57675,160'ND 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: 0 155 0 40 69 Subsequent to operation: 0 4300 1 50 161 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory❑ Development❑✓ Service H Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑✓ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ 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: 316-598 Contact Taylor Wellman-777-8449 Email twellman@hilcorp.com Printed Name Chad Helgeson Title Operations Manager ;01,7, Signature (.rt- �— Phone 907-777-8405 Date 7II1/,7 Form 10-404 Revised 5/2015 0-11 . �_ 07 RBDMS L LFEB 1 4 2017 Submit Original Only - S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 11/18/2016- Friday PTW and 1SA. Mobe to location. Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. RIH w/4- 1/2" CIBP and tied into SLB Platform Express log dated 26-Aug-2000. Run correlation log and send to town. Get ok to set plug at 7,270'. Set plug with 250 psi on plug. Lost 100 lbs of line wt when set. Pick up 30' and go back and tag plug. POOH. Setting tool looked good. RIH w/3" x 30' dump bailer with 8 gals cement and tag plug. Dump cement on top of plug at 7,270'. Made another run with bailer which made it 16 gals of cement (25'total cement on top of plug). Cement in place at 2130 hrs and est TOC at 7,245'. Both dumps good. RIH with 1-9/16" x 2' tubing punch and punched 9 holes from 5,406' to 5,408'. Holes punched in pup below packer. Sent log to town. Saw no pressure increase. POOH. All shots fired. Rig down lubricator and turn well over to field. 11/25/2016- Friday Finish loading tubing with KCL. PTW and 1SA. Rig up lubricator and pressure test tubing plug to 1,500 psi (good)and lubricator to 2,000 psi. RIH w/3-5/8" chemical cutter and tie into schematic. Run correlation log. Get ok to cut tubing at 5389' (5' into first full joint above packer). Spot cutter with 260 psi on tubing and 60 psi on IA. Fired cutter and tubing and IA equalized. POOH. Rig down lubricator and turn well over to field. 11/26/2016-Saturday PJSM, off-loaded equipmen. Laid contentment and spotted beam, choke building, pit and pump building. SDFN. 11/27/2016 -Sunday Held PSJM, discussed daily activities. Spotting equipment, Koomey unit, diesel tank and Gen unit. Sealed in 3 sides on the the 75' x 100' containment. Finished winterization for associated rig equipment. Laid out Koomey lines and kill/CK lines and winterized same. Installed gas buster on pit. Hooked-up circulating lines for pump, pit and manifolds. SDFN. 11/28/2016- Monday Held PJSM, discussed daily activities. Installed matting walkways around rig to reduce slipping hazards. Covered tree and heated. Waited for carrier to be delivered from SD-5. Off-loaded carrier and removed floor from sub-base so rig would fit due to tree orientation. RU drill console and mini beam. Spotted carrier and raised derrick. Disconnect and moved gen set. Repositioned manifold connex so kill/ck lines would MU to BOP stack. Spotted gen set and reconnected power. Hooked-up a blow down tank to tree. SITP 10psi. Bled off tbg psi and set a BPV. MU Kelly hose to csg and bled off to rig pit. ND production tree, had to use a torque wrench and wench line to break bottom connection and a test pump to pump tree off seat. SDFN. Night watch on tower. • s • Hilcorp Alaska, LLC Well Operations Summary f° LAD ( Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 2{p 1 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 11/29/2016-Tuesday Held PJSM, discussed daily ops and hazards involved with working in cold weather. NU 11" BOP. Stack mud cross w/2- 1/6" 5M manual Kill/ck valve and 2-1/16" 5M HCR kill/ck valve, double gate blinds on bottom and 2-7/8"-5" VBR's on top and 11" 5M Hydril. MU kill/ck lines from stack to manifolds and winterized. Connected Koomey hoses and winterized. RU floor and BOP skirting. Installed windwalls and stairwell. Ran heated ducts to inside BOP skirting. Hung vis-queen over drill console and draw works. Hooked up test pump to gen. Cleared and cleaned walkways around rig. Finished sealing in containment around rig. Loaded pit with 60bbls of 3% KCL. PU 2-7/8" test jt with 4-1/2" BTC sub on bottom and could not get the threads to make up. Made several attempts with no luck. Called OSK and found test plugs to test BOP's in the AM. Working on finding another sub to pull hanger. SDFN. Night watch on tower. 11/30/2016-Wednesday Held PJSM, chained BOP stack to rig beam. MU 2-7/8" test jt with 7" test donut. Flooded BOPE and circulated thru same. Closed annular and shell tested BOPE to21500psi, lost 400psi_in 5mins. Could not find any surface leaks. Troubleshoot problem. Pulled and replaced TWC. Closed blinds and performed shell test to 2,500psi-bled off 150psi in 5mins. Troubleshoot and found small leak on the kill line flange.Tightened and shell tested 2,500psi=Good Test. PU 2- 7/8" test jt. Closed annular and shell tested 2,500psi=Good Test. With AOGCC Inspector Jeff Jones preformed BOPE Test w/2-7/8" and 4-1/2" test jts, annular 250psi/2,500psi, valves 250psi/2500psi, Rams 250psi/2,500psi, held and charted 5 mpt,gas detection and Koomey drawdown. Tested all heather LEL shutdowns. No failures recorded. SDFN. Night watch on tower. 12/01/2016-Thursday Held PJSM, discussed daily ops. Cut and slip drill line. Removed snow out of containment and walkways around rig. Set catwalk and pipe racks. PU/MU YC elevators and RU McCoy tongs and connected power pack. Found the wrong dies installed in the tongs. Rig time waited on tong dies to arrive from Moncla's shop. PU 6'4-1/2" xo Sub BTC Pin x IBT and 1 jt of 4-1/2" IBT torqued sub to 3,500psi. MU landing jt in the tbg hanger. BOLDS and opened csg to gas the gas buster. PU and pulled hanger free at 55K(string weight), pulled 20K over string weight and cut section of the 4-1/2" tbg came free. Pulled hanger to rig floor, BO/LD landing jt, tbg hanger and disconnect 1/4" control line. Prepared to L/D 4-1/2" tbg.TOH with 31 jts of 4-1/2" 12.6# IBT L-80 tbg and cut 1/4" control line every jt.Visually inspected tbg good while L/D jts. Secured well. SDFN. Night watch on tower. 12/02/2016- Friday Held PJSM, discussed daily activities with crew.TOH L/D 97 Jts of 4-1/2" 12.6# IBT L-80, 4-1/2" chemical injection sub, 4-1/2" GLM and 1 cut joint. All joints visually inspected good. Clean cut on TOF. Recovered 23 3/4" SS bands, 5 still in the hole. Cleaned and cleared rig floor, MU handling tools for milling BHA. Racked milling BHA and 4-3/4" drill collars and tallied. PU/MU packer milling BHA total length 164.14': 5.57' burn shoe (6" OD 5-1/4" ID). 11.19' 2 Ext (6" OD 5- 3/8" ID). 2.60'top bushing (6" OD 2-3/8" ID). 7.86' bumper jars. 12.39' oil jars. 122.81' 4 drill collars (4-3/4" OD-4- 1/4" ID). 1.12' cross over(4-3/4"OD- 2-3/8"ID). LD 2-7/8" shoulder elevators and PU/MU 2-7/8" MYT elevators. RIH w/BHA and 1'Jts of 2-7/8" 7.9# PH6 P110 tbg and set in slips. Secured well and SDFN. Night rig watch on tower. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 12/03/2016-Saturday Held PJSM and discussed daily ops. RD McCoy csg tongs, RU Foster tbg tongs and 2-7/8" handling tools.TIH w/packer milling BHA and 173 jts of 2-7/8" 7.9# PH6 P110 workstring tbg. Tagged packer @ 5,385' and LD tag jts. Cleared and cleaned rig floor. Swapped MYT elevators with shoulder elevators. NU 7-1/6" 5M x 11" 5M crossover spool and a halls head circulating head. PU/MU power swivel tested and Kelly hose tested 250-2,500psi-good test. Racked back swivel in the goose neck. Secured well and SDFN. Night watch on tower. 12/04/2016-Sunday Held PJSM and discuss daily ops. MU 10' 2-7/8" PH-6 pup jts. Stripped halls head rubber over same. Screwed in the power swivel to the workstring and it would not go in neutral. SD power pack. Repairs on swivel. Changed out the panel for the swivel. Functioned tested power swivel good. Screwed the swivel into the workstring. Rolled the mud pump over at 2bpm and broke circulation at 700psi. Established parameters PU 40K/SO 39K, SO and engaged and started burning over packer 2K dn torque 2,500psi. Continued milling packer 3K down/torque 2,500psi-3800psi, 2bpm/700psi, returns of metal cuttings. Made about 16" of hole. Continued milling and lost circulation and SD pump. Picked up off packer and w/30K over pull, SO and workstring came free. Started pumping at 2bpm/700psi with full returns. SO and 3K down and lost returns and no torque on shoe. Made several attempts with the same results. PU off packer with 2-3K over pull. Contacted engineer and discussed plan and decided to TOH. RD power swivel, halls head and XO spool. Changed out shoulder elevators with MYT.TOH standing back 2-7/8" workstring and 4-3/4" drill collars, LD and inspected burn shoe. Sent pic to engineer. Discuss plan in the AM. Secured well and SDFN. 12/05/2016- Monday Held PJSM, discussed plan forward with engineer, LD 5-3/4" Ext, PU/MU and tallied BHA#2 and TIH as follows: 5- 3/4" OS loaded w/4-1/2" Grapple, 4-3/4" bumper Jar, 4-3/4" oil jar,4-4-3/4" spiral DC, 4-3/4" accelerator jar and 86 stands of 2-7/8" PH6. Swapped MYT with YT elevators. Established parameters 40K up/39K dn, PU 10' 2-7/8" PH6 pup jt and engaged TOF @ 5,380' with 20K down. PU 20K over to ensure good catch. Jarred on fish at 50K over and pick ups to 70K over.Jarred fish 4x and pulled free. Swapped back to MYT elevators and TOH standing back workstring. LD OS and inspected.The grapple and was pulled out of the OS leaving just a 1" piece of grapple inside the over shot. PU/MU BHA#3 and TIH as following, 6" burn shoe 5.14" ID, 2-6" wash pipe ext, 4-3/4" BJ, 4-3/4" OJ, 4-4-3/4" spiral DC and 2-7/8" PH6 workstring. Set in slips. Secured well and SDFN. Night watch on tower. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 12/06/2016-Tuesday Held PJSM, discussed daily ops. Continued TIH with BHA#3 burn shoe with 86 stand of 2-7/8" PH6. Set in slips and PU handling tools for swivel and RU the power swivel and 10' 2-7/8" PH6 pup jt. Established parameters Up/Dn 40K/39K. Broke circ at 2bpm/500psi 100rpm's. SO and tagged @ 5,390' and milled off junk. SD swivel, closed pipe rams and rev circulated at 4bpm until returns cleaned up. Returns metal cuttings and rubber shavings.Slowed pump rate to 2bpm/500psi and opened pipe rams. Slacked off rotating pipe 100 rpm's milled on packer monitoring returns lite rubber and metal shavings. Made about 1' of hole. Cont milling on packer, 2 hrs of not making any progress.The burn shoe shows to be torqueing and cutting but not making any hole and no cuttings at surface. SD power swivel and pump. Blew down Kelly hose. Hung swivel back in the derrick. Secured well and SDFN. Night watch on tower. 12/07/2016-Wednesday Held PJSM, discussed daily activities.TOH with standing back 2-7/8" workstring and DC. LD Jars and burn shoe. Burn shoe was 100%worn with marks inside about 1' showing it going over fish. Sent pic to town. PU/MU test jt and test plug. Flooded and circulated stack. Closed in BOPE and shell tested to 250-2,500psi, good test. Contacted AOGCC inspector we ready to test. With AOGCC Inspector Matt Herrera preformed BOPE Test w/2-7/8" and 4-1/2" test jts, annular 250psi/2,500psi, valves 250psi/2,500psi, rams 250psi/2,500psi, held and charted 5mpt,gas detection and Koomey drawdown. Tested all heaters LEL shutdowns. No failures recorded. PU/MU packer milling BHA#4 total length 163.14': 4.57' burn shoe (6" OD- 5-1/4" ID); 11.19' 2 Ext (6" OD-5-3/8" ID); 2.60'top bushing (6" OD- 2-3/8" ID); 7.86' bumper jars; 12.39' oil jars; 122.81" 4 drill collars (4-3/4"OD- 4-1/4" ID); 1.12" cross over(4-3/4"OD- 2-3/8"ID). TIH w/BHA#4 and 82 stands of 2-7/8" workstring to 10' off the TOF. Set pipe in slips. Secured well and SDFN. Night watch on tower. 12/08/2016-Thursday Held PJSM. RU the power swivel and MU 2 10' pup jts. Started pump at 2.5bpm/700psi broke circulation. Established parameters UP/DN/RPM's 40K/38K/100. SO and tagged TOF 8,380' milled off junk and continued SO and engaged packer. Continued milling down to 8,395' torqueing 2,500psi to 3,500psi. Returns of metal shavings while milling. Continued rotating at 9,395' with no torque and returns clean. SD pump and LD power swivel. TOH w/BHA#4. LD washpipe ext and burn shoe. Shoe was 100%worn. Sent pic to town. PU/MU BHA#2 and tallied. TIH as follows: 5- 3/4" OS loaded w/4-1/2" grapple, 4-3/4" bumper jar,4-3/4" oil jar, 4-4-3/4" spiral DC, 4-3/4" accelerator jar and 86 stands of 2-7/8" PH6. Swapped MYT with YT elevators. Established parameters 40K up/39K dn. PU 10' 2-7/8" PH6 pup jt and engaged TOF @ 5,380' with 20K down. PU 20K over to ensure good catch. Jarred on fish at 50K over and pick ups to 70K over.Jarred fish 4x and fish came free. PU 10' and packer hung up jarred free. PU to the next tool jt. LD the single.TOH standing back workstring and BHA. L/D over shot Baker S3 packer, X-nipple, 3 jts of 4-1/2 IBT and mule shoe. Secured well and SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 12/09/2016- Friday Held PJSM and discussed daily activities. Spotted Pollard EL Unit/Rig Up. MU/CCL, weight bar,junk basket, 3.63" GR. RIH w/same and tagged 7,164' ELM. POOH L/D JB and GR. M/U 6.10"JB and 5.63" GR and RIH w/same, tagged TOL @ cAL 5,540' ELM. POOH LID JB and GR. M/U CBL logging tool and RIH to 5,338'. Logged up from 5,338' to 1,850'. POOH LD logging tool and RDMO Pollard EL unit.TIH w/85 stand of 2-7/8" PH6 workstring. Set in slips. MU Kelly hose and rev circulated bottoms up. Returns clean. LID power swivel and YT elevators from rig floor. TOH L/D 170 jts of 2-7/8" PH6. LD Foster power tongs and RU McCoy power tongs and 4-1/2'YC elevators. 12/10/2016-Saturday Held PJSM, discussed daily activities. Held well control drill with crew. Racked and tallied 4-1/2" 12.6# L-80 IBT tbg. Tallied all pup jts and completion jewelry. MU 4-1/2" YC elevators and McCoy tongs. PU/MU 4-1/2" completion string and TIH w/same torqueing connection to 3,000psi. PU/MU tbg hanger and landing jt. String weight 47K Up/43K SO. Landed completion with 45K on tbg hanger. RILDS 4-1/2' completion string as follows: WLEG @ 4,910'; 4-1/2" 12.6# L- 80 IBT Pup; X-nipple @ 4,901'; 4-1/2" 12.6# L-80 IBT Pup; 4-1/2" 12.6# L-80 IBT Pup; Packer @ 4,886';4-1/2" 12.6# L- 80 IBT Pup; 4-1/2" 12.6# L-80 IBT Pup; X-nipple @ 4,863'; 1 it 4-1/2" 12.6# L-80 IBT Tbg; 4-1/2" 12.6# L-80 IBT Pup; GLM (Dummy) @ 4,810'; 4-1/2" 12.6# L-80 IBT Pup; 115 jts 4-1/2" 12.6# L-80 IBT Tbg and Tbg Hanger. Dropped ball and waited for ball to seat. Opened csg. MU Kelly hose and pressured up to 3,800psi on tbg to set packer. With leak- off made several attempts and could not get pressure to flat line. Held pressure on tbg for 30mins.Tbg bled off to 2,300psi with no leaks at surface or fluid leaking out of the csg. NOTE: RHCP leaking by. Will retest post rig with SL. Opened tbg. MU Kelly hose to csg and pressured up to 2,600psi. Charted and held for 30mins, Good Test. Bled off pressure. BO/LD landing jt and Set BPV. Secured well and SDFN. Night watch on tower. 12/11/2016-Sunday Held PJSM and discussed daily activities. Cleaned and cleared rig floor. LD stairwell, windwalls and BOP skirt, RD floor and secured. RD kill/choke lines and control lines for Koomey unit. ND 11" BOP stack and NU production tree and PT 5,000psi,good test. Pulled BPV. Disconnected generator and rolled up power cables, RD gas buster and emptied pit. Disconnected circulating lines from pump, pit and manifolds. BO guide line cables and lowered derrick. Removed winterization for rig. RDMO Moncla 401, loaded associated rig equipment and MOBE to Swanson. Carrier will be hauled in the AM. Cleaned location. 12/12/2016- Monday MIRU SL, PT to 3,000psi.TIH w/2-1/2"JDC w/2.7" bell guide to 4,871' KB. W/tool latched, PU 20' then reset bar in RHCP and pressure up to 1,000psi held 20mins, good test. Pressured to 2,000psi held 20mins,good test. MIRU Triplex, PT tbg to 3,000psi, held for 30 mins with leak-off. POOH w/drop bar. RIH w/4" GS w/packoff plug to 4,869' KB and set same. POOH LD lub and SDFN. 12/13/2016-Tuesday Packoff set on plug body the night before, pressure test tubing to 3,000 psi 30 mins,good test. RIH and pull packoff and RHCP plug body. RDMO. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 12/15/2016-Thursday Obtain PTW. Hold safety meeting and discuss procedure. Fire equipment. RU CTU 12 with 1.75" CT. AOGCC 24 BOPE test witness notification sent 12/14/16 @ 1100. Witness waived by Jim Regg on 12/14/16 @ 11:14 hrs. Start BOPE test. Test all rams and valves to 250 low 4,500 high. Accumulator draw down test. BOPE test complete. No failures. Submit BOPE test report to state. Secure well head.Tarp tree and install parachute to keep well head thawed. SLB crews off location. Air liquid order of N2 will be onsite in the AM. 12/16/2016- Friday Obtain PTW. Hold safety meeting. Discuss JSA and review job procedure. Emphasize on snow conditions and snow removal. Uneven surfaces under fresh 4" of snow. Fire equipment. Pick injector head. Stab 10' lubricator. Make up 1.9" OD CC, 2" x 2.0" OD MBT, 2.0" Ball drop reverse circ nozzle. Stab on well. Pressure test stack to 250/4,500 psi. Open master swab. 0 psi whp.Transfer N2 from air liquid into SLB N2 pump. Start cooling down N2. RIH with 1.75" CT. PT N2 lines 250/4,500 psi. Online with N2 down CT x tubing annuli. 600 scf/min. Increase rate to 800 scf/min. Water returns at tank. Continue IH and tag at 7,202' CTMD. Pick up weight clean. Lost returns. WHP increasing. End of coil plugged off with debris. Shut down N2 pump. Pick up OOH to 6,800'. Returns established. TIH, RIH to 7,195' and coil plugged off again. Shut down N2 pump. Online down CT string with field triplex to dislodge debris in coil. Pressure increased to 1,300 psi and broke over. Parked at 7,190' and continue to reverse N2 lift well bore fluids. 132 bbls returned coil blowing dry. Start POOH. POOH to surface, WHP 2,450. Bleed down wellhead. At surface. Close master swab. 1,184 psi SITP. Start rigging down CTU 12. G&I/vac truck tank straps show 146 bbls returned. Tape measure tank straps from return tank show 132 bbls returned. 2,000 gallons of N2 pumped for lift. Wellhead secure. Equipment parked on edge of pad. Crews off location. a • IIHilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 12/21/2016-Wednesday Rig up lubricator and PT lub to 250 psi low and 2,500 psi high. Found a kink and with wore spot. Pull off 200' of wireline and re-headed. Arm gun.TP 1,164 psi. RIH with 2-7/8" x 18' millennium HC, 6 spf, 60 deg perf gun and tie into SLB Platform Express log dated 26-Aug-2000. Run correlation log and send to town. Get ok to perforate from 6,962' to 6,980. Bled tubing from 1,164 psi to 1,050 psi. Spotted shot and fired gun from 6,962' to 6,980' with 1,050 psi on tubing. After 5 min pressure was 1,041 psi. Gun was dry.All shots fired. RIH with 2-7/8" x 18' millennium HC, 6 spf, 60 deg perf gun and tie into SLB Platform Express log dated 26-Aug-2000. Run correlation log and send to town. Get ok to perforate from 6,776' to 6,794'. Spotted shot and fired gun from 6,776' to 6,794' with 1,041 psi on tubing.After 5 min pressure was 1,053 psi. POOH. Gun was dry. All shots fired. RIH with 2-7/8" x 20' millennium HC, 6 spf, 60 deg perf gun and tie into SLB Platform Express log dated 26-Aug-2000. Run correlation log and send to town. Get ok to perforate from 6,637' to 6,657'. Spotted shot and fired gun with 1,265 psi on tubing. After 5 min pressure was 1,271 psi. POOH, gun was dry. All shots fired. RIH with 2-7/8" x 20' millennium HC, 6 spf, 60 deg perf gun and tie into SLB Platform Express log dated 26-Aug-2000. Run correlation log and send to town. Get ok to perforate from 6,570' to 6,590'. Spotted shot and fired gun with 1,318 psi on tubing. After 5 min pressure was 1,295 psi and dropping slowly. POOH, gun was dry. All shots fired. RIH with 2-7/8" x 6' millennium HC, 6 spf, 60 deg perf gun and tie into SLB Platform Express log dated 26-Aug-2000. Run correlation log and send to town. Get ok to perforate from 6,508' to 6,514'. Spotted shot and fired gun with 1,138 psi on tubing. After 5 min pressure was 1,130 psi and dropping slowly. POOH, gun was dry. All shots fired. Rig down lubricator and turn well over to field. 01/12/2017 -Thursday Sign in. PTW and JSA. Mobe to location and spot equipment. Rig up lubricator. Swab froze, o-ring leak, bring heater in to thaw out swab. PT to 250 psi low and 2,000 high. RIH w/2-7/8" x 20' Connex HC, 6 spf, 60 deg phase, while well is flowing 888 at 263 psi and tie into Platform Express log dated 13-Aug-2000. Run correlation log and send to town. Get ok to perf from 5,034' to 5,054'. Spot shot and fired with 258 psi flowing. After 30 min TP-449 psi at 1557.65 MCF/d. POOH, all shoots fired. RIH w/2-7/8" x 6' Connex HC, 6 spf, 60 deg phase, while well is flowing 1.5 million at 452 psi and tie into Platform Express log dated 13-Aug-2000. Run correlation log and send to town. Get ok to perf from 4,989' to 4,995'. Spot shot and fired with 452 psi flow at 1.5 million.After 20 min TP -453 psi at 1.55 MCF/d. POOH, all shoots fired. Rig down lubricator and turn well over to field. i i Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KTU 32-07 50-133-20491-00 200-023 11/18/16 1/20/17 Daily Operations: 01/20/2017 - Friday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. RIH w/2-7/8" x 20' Connex HC, 6 spf, 60 deg phase perf gun while well is flowing 2.580 mil at 2,71.2 psi and tie into Platform Express log dated 13-Aug-2000. Run correlation log and send to town. Get ok to perf from 5,054' to 5,074' (UB-1). Fired gun and after 5 min 2.917 mil at 287.7 psi and slowly climbing.After 20 min 3.2 mil at 293 psi. POOH. Gun was wet. RIH w/2-7/8" x 18' Connex HC, 6 spf, 60 deg phase perf gun while well is flowing 3.738 mil at 310 psi and tie into Platform Express log dated 13-Aug-2000. Run correlation log and send to town. Get ok to perf from 5,410' to 5,428' (UB-5B). Fired gun and after 5 min rate the same and 311 psi. POOH. Gun was wet. RIH w/2-7/8" x 14' Connex HC, 6 spf, 60 deg phase perf gun while well is flowing 3.577 mil at 313 psi and tie into Platform Express log dated 13-Aug-2000. Run correlation log and send to town. Get ok to perf from 5,384' to 5,398' (UB-5B). Fired gun and after 5 min rate 3.657 and 315 psi. POOH. Gun was wet. RIH w/2-7/8" x 24'Connex HC, 6 spf, 60 deg phase perf gun while well is flowing 3.553 mil at 315 psi and tie into Platform Express log dated 13-Aug-2000. Run correlation log and send to town. Get ok to perf from 5,353' to 5,377' (UB-5A). Fired gun and after 5 min rate 3.574 and 316 psi. POOH. Gun was wet. RIH w/2-7/8" x 11' Connex HC, 6 spf, 60 deg phase perf gun while well is flowing 3.560 mil at 316 psi and tie into Platform Express log dated 13-Aug-2000. Run correlation log and send to town. Get ok to perf from 5,333' to 5,344' (UB-5). Fired gun and after 5 min rate 3.595 mil and 316 psi. POOH. Gun was wet. RIH w/GPT tool logging down and it appears to be gas cut fluid from 5,060' to 6,790'. Looks like solid fluid from there on down. Pollard will send log by in the morning. Rig down lubricator and turn well over to field. . 41, Kenai Field .... Well: KTUGas 32-0 SCHEMATIC Last Completed: 12/11/2016 Hilcorp Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21' Size Type Wt/Grade/Conn ID Top Btm �a v 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' §1 . 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' 7" Intermediate 23/L-80/N/A 6.366 Surface 5,040' fig" 29/P-110/N/A 6.184 5,040' 5,690' 74 +:4 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' a:, ``} TUBING DETAIL 15/8"'il,' ,uir" ;r ( 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 4,910' Max Inclination ° 1JEWELRY DETAIL 28.74°@ 2,771' In ,4 2 4'a ,, No Depth ID ID Item ` 3 1 4,803' 3.833" 5.875" 4-1/2"GL Mandrel,KB-2,Bottom Latch(Dmy GLV 12/10/16) '' !_, 2 4,862' 3.813" 5.030" X Nipple 4 3 4,881' 3.958" 5.20" 4-1/2"x7"Tripoint Perm Packer w a 5 4 4,900' 3.813" 3.813" X nipple 'I 5 4,910' 3.958" 5.20" WLEG '° UB-X 6 5,540' N/A N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR 7 7,270' N/A N/A 4-1/2"CIBP Capped with 25'Cement- set 11/18/16 8 7,540' N/A N/A CIBP UB1 - 9 7,596' N/A N/A CIBP Capped with 25'Cement L85 10 9,050' N/A N/A HES Gun Hangar 11 9,074' N/A N/A HES 10K EZ Drill UB-5A UB-5B PERFORATION DETAIL '=" ':' 6 Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Date Status UB-X 4,989' 4,995' 4,671' 4,677' 6 6 01/12/17 Open ,e ,-, , UB-1 5,034' 5,054' 4,711' 4,729' 20 6 01/12/17 Open U13-1 5,054' 5,074' 4,729' 4,747' 20 6 01/20/17 Open ! .1,5ii • UB-5 5,333' 5,344' 4,977' 4,986' 11 6 01/20/17 Open UB-5A 5,353' 5,377' 4,994' 5,015' 24 6 01/20/17 Open UB-5B 5,384' 5,398' 5,022' 5,034' 14 6 01/20/17 Open i 1.13-1 UB-58 5,410' 5,428' 5,045' 5,061' 18 6 01/10/17 Open ^' ;.7.. 13-3 LB-1 6,508' 6,514' 6,054' 6,060' 6 6 12/21/2016 Open +: L65 LB-3 6,570' 6,590' 6,114' 6,133' 20 6 12/21/2016 Open TOC@7,245'11/19/16 t sr LB-7 LB-5 6,637' 6,657' 6,179' 6,198' 20 6 12/21/2016 Open " tlLB-7 6,776' 6,794 6,314' 6,332' 18 6 12/21/2016 Open ''rwksrl.r! 7 LB 6,962' 6,980' 6,497' 6,515' 18 6 12/21/2016 Open 01 LB-4B 7,293' 7,313' 6,825' 6,845' 20 6 08/18/2015 Isolated " •%,; L3r76 LB-4D 7,376' 7,390' 6,908' 6,922' 14 6 08/18/2015 Isolated "�* LB-5B 7,495' 7,515' 7,027' 7,047' 20 6 08/18/2015 Isolated L 3-40 + T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 01/09/2001 Isolated L135B T 73 1 7,703' 7,710' 7,234' 7,241' 7' 6 01/09/2001 Isolated 01 4T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 01/09/2001 Isolated 8 T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 01/09/2001 Isolated g T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 09/29/2000 Isolated ,,,4 T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 09/13/2000 Isolated 71 * Fish 9,027 - P t 4.•; �m;;, CEMENTING DETAIL i prl�lilt 10 Casing Detail 41/2" 7' •.11 9-5/8" 12-1/4"hole w/400sks of cement 7" 8-1/2"hole w/445sks of cement 4-1/2" 6-1/8"hole w/675sks of cement PBTD=9,047 MD/8,578'TVD 1D=9,117 MD/8,648 ND Updated by DMA 02-14-17 • 2.o0- 02. 3 Seth Nolan Hilcorp Alaska, LC 2-1 GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 fiI nrp Mask■,I JA, EC E I� ' Fax: 907 777-8510 i. M E-mail: snolan@hilcorp.com DATA LOGGED 0 NOV 2 2 2016 '�f< SEWER tkOGCC DATE 11/18/2016 To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCIdiED APR 2 12017 KTU 32-07 CD: Final Well Data KTU 32_07_1ft_step.LAS 2/512013 9:57 AM LAS File 4,035 KB KTU 32_07_haif_ft step.LAS 2/5/2013 9:58 AM LAS File 11,720 KB KTU_32-07_ait_1900-5700.pdf 11/18/2016 11:31 AM PDF Document 2,745 KB • KT1.1_32-07_ait_1100-5700.TIF 11/18/2016 9:09 AM TIF File 5,774 KB ▪ KTU_32-07_caliper_1900-5700.pdf 11/18/2016 11:30 AM PDF Document 467 KB KTU_32-07 caliper_1100-5700.TIF 114(18/2016 8:56 AM TIF File 1,029 KB • KTU_32-07_GR_den_neut PEX tin-5in.tif 11/17/2016 2:17 PM TIF File 261,303 KB KT1_32-07_GR_RES_PEX_2in-5in.pdf 11/18/2016 11:28 AM PDF Document 52,591 KB • KTU_32-07_GR_RES_PEX_2in-5in.tif 11/17/2016 2:25 PM TIF File 295,168 KB KTU_32-07Mudlog_2in.pdf 11/18/2016 11:25 AM PDF Document 6,736 KB KTU_32-07 Mudlog_2in.tif 11/18/2016 8:20 AM TIF File 42,516 KB KTU_32-07_OHL.LAS 1.1/18/2016 12:39 PM LAS File 2,063 KB KTU_32-07_poro1900-5200.pdf 11/18/2016 11:27 AM PDF Document 3,047 KB u KTU_32-07_poro 1900-5200.TIF 11/18/2016 8:52 AM TIF File 6,161 KB A▪ d KTU 32-07_RFT.pdf 11/18/2016 11:23 AM PDF Document 890 KB • KTU_32-07 RFT.TIF 11/18/2016 9:11 AM TIF File 1,827 KB ktu_32-7 mudlog.las 1/24/2013 11:40 AM LAS File 4,618 KB PLAY_093MAIN.las 413/2000 5:03 AM LAS File 1,117 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By. Date: • 0 .to OF riff, • is) • yy�. �A THE STATE Alaska Oil and Gas �� --s��A. A o e T a T e Conservation Commission N �� f1ZL1�1S]��.1Z AA �� 333 West Seventh Avenue �I'lr1r.- '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *, • .•• Main: 907.279.1433 Off"ALAS1" Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson , n17, Operations Manager SCpNNE Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool, KTU 32-07 Permit to Drill Number: 200-023 Sundry Number: 316-598 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, P24&/ii Cath P. Foerster Chair DATED this 44.---day of November, 2016. RDDIV9S L'NOV 2 8 2818 RECEIVED STATE OF ALASKA NOV 2 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A CC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N2 Jet/Displacement 0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development 0 200-023 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20491-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510a Kenai Tyonek Unit(KTU)32-07 Will planned perforations require a spacing exception? Yes El No No E 9.Property Designation(Lease Number): 10.Field/Pool(s): A-028142 Kenai Gas Field-Beluga/Upper Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 9,117' 8,648' 9,047' 8,578' Pre 957psi;Post 1,780psi 7,540';7,596' 8,191'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 123' 13-3/8" 123' 123' 3,090 psi 1,540 psi Surface 1,510' 9-5/8" 1,510' 1,509' 5,750 psi 3,090 psi Intermediate 5,040' 7" 5,040' 4,717' 6,340 psi 3,830 psi Intermediate 650' 7" 5,690' 5,294' 11,220 psi 8,530 psi Liner 3,577' 4-1/2" 9,117' 8,548' 8,430 psi 7,500 psi 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 5,540' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): S-3&ZXP Packer and N/A 5,400'MD/5,036'ND&5,540'MD/5,160'ND and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: November 25,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman-777-8449 Email twellmanCc�hilcorp.com Printed Name ChadHelgeson Title Operations Manager Signature /////t Phone 907-777-8405 Date )1/41/1 4P COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S, Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: `7 j (3 %Q t- 1W Iti t1ib Post Initial Injection MIT Req'd? Yes ❑ No / Spacing Exception Required? Yes ❑ No Subsequent Form Required: () — f 1-1 RB® IS /j v NOV2Ui APPROVED BY Approved by:R COMMISSIONER THE COMMISSION Date: ll-2,2--)/e„,y4,04,,,,,,,z__ Ae 44 11-Z2 OIfife4Io .. a/fSubmitFormand Form 10-403 Revised 11/2015 tad for 12 months from the date of approval. Attachments in Duplicate • S Hilcorp Alaska,LLC Post Office Box 244027 RECEIVED Anchorage,AK 99524-4027 3800 Centerpoint Drive NOV 2 1 2016 Suite 100 �+ Anchorage,AK 99503 November 21, 2016 AOGCC Mr. Guy Schwartz Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: KTU 32-07 (PTD 200-023) Sundry 316-574 Change Dear Mr. Schwartz: Hilcorp would like to cancel or withdrawal Sundry #316-574 for the rig workover on Kenai Unit Well KTU 32-07 PTD 200-023 and re'lace with the attached 10-403 sund re'uest. This new application has additional perfs and removed a CIBP from the program. We anticipate starting this wellwork with the Moncla rig November 25th Should you have any additional questions, please contact Chad Helgeson (777-8405 or chelgeson@hilcorp.com) or Taylor Wellman(777-8449 or twellman@hilcorp.com) Sincerely, HILCORP ALASKA, LLC Chad A Helgeson Operations Manager 10-403 application request • RWO Revision#1 Well: KTU 32-07 11°''"'p.aia.k",1.L Date: 10/26/2016 Well Name: KTU 32-07 API Number: 50-133-20491-00 Current Status: Online Gas Well Leg: N/A Estimated Start Date: 11/25/16 Rig: Moncla 401 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-023 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Surface Pressure: 65 psi Maximum Expected BHP (Current): 1620 psi @ 6,825' TVD Max. Potential Surface Pressure (Current): 957 psi (0.1 psi/ft to surface) Maximum Expected BHP (Post add UB-7): 2290 psi @ 5,093' TVD Max. Potential Surface Pressure (Post add UB-7): 1780 psi (0.1 psi/ft to surface) Brief Well Summary Kenai Tyonek Unit 32-07 (KTU 32-07) is a Tyonek producer drilled in 2000 with the perforated interval ranging from the Tyonek 72-8 sand at 7652' MD to the Tyonek 86-2 sand at 9042' MD. Since the beginning of production this interval has had problems staying above the critical velocity to keep the well unloaded. Water production began at small rates (<1BWPD) initially but increased to 10 BWPD within the first two years of production. The completion is a 4.5" monobore with a chemical injection mandrel at 2099' and a gas lift mandrel at 5007'. The well was able to produce above the unloading rate briefly in 2003 but was unable to maintain this rate. A SBHP measured on 7/7/2010 showed the formation has 1320 psi. On 9/08/2013 operators attempted to flow the well. Sand production filled the tubing to above the top perf with the last tag at 6467' SLM on 9/22/2013. The well was cleaned out to 8,191' CTM in March 2014 using coil tubing. A planned velocity string in 2014 was never installed. The purpose of this work/sundry is isolate the existing perforations and to recomplete the well uphole to allow for production from the UB-7, UB-5, UB-3, UB-1, and UB-X sands. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter, i.e. near flow-back tank. • Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) • Ensure all crews are aware of stop job authority Pre-Sundry Operations Slickline Procedure: -Completed 11/4/16 drift w/3.75" cent&3.75" GR to 7524' md. 1. MIRU Slickline, pressure test lubricator to 250psi low and 2000psi high. 2. MU 3.625" dummy plug toolstring and drift past 7,250' md. a. This drift will work for the deepset CIBP and the tubing cutter to be used at a later step. 3. RD Slickline unit. Sundried Operations—All operations beyond this point will require the approved sundry E-Line Procedure: 4. MIRU E-Line unit. Pressure test to 250psi low/2000psi high. 5. MU 4-1/2" CIBP toolstring. RWO • Revision#1 • Well: KTU 32-07 Hilcoru Alaska,Is) Date: 10/26/2016 6. RIH and set CIBP at+/-7,270' md. POOH. / 7. Dump 25' (16.0 gal)of cement on top of the CIBP. 8. MU and RIH w/4-1/2" tubing puncher. C:P 9. Use CCL to correlate and punch tubing from +1-5406' to+/-5408' md. a. This is in the mid pup joint below the packer. 10. POOH and RD E-Line unit. Pumping Procedure: 11. Load tubing with 3% KCI (8.5ppg). a. Tbg FL shot @ 2880' and on 11/2/16: 4-1/2" Tubing volume to 4-1/2" CIBP (0.0152bpf x 2,880') =44bbls �� b. IA FL shot @ 1883' on 11/2/16: 4-1/2"Tubing x 7" annular volume below packer �0c, (0.0175bpf x 1,883') = 33bbls k ?v'n c. Total = 77bbls rs5 12. Pressure test the_plug to 1500Qsir. 13. Bleed down tubing pressure to "200psi upon test completion. 14. Load IA with with 3% KCI (8.5ppg). E-Line Procedure: 15. RU E-Line unit and pressure test to 250psi low/2000psi high. 16. RIH and tag cement top. 17. MU and RIH w/4-1/2" chem cutter. 18. Chem cut tubing at+/-5,398' and (mid pup joint directly above the packer). -14 a. Correlate to the KTU 32-07 tubing tally. b. Ensure tubing pressure is above IA pressure prior to cut. c. Note pressure equalization in after cut in report. 19. RD E-Line unit. WO Rig Procedure: 20. MIRU Moncla#401 WO Rig. 21. Confirm tubing pressure is Opsi. 22. Set 4" BPV. ND Tree. 23. NU 11" BOPE. Pull BPV. Set TWC. Test to 250 psi Low/2,500 psi High, annular to 250 psi Low/ 1,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8" test joint. 24. Bleed any pressure off tubing. Pull TWC. 25. Pull 4-1/2" tubing and rack back joints as needed down to the tubing cut at+/-5,398' md. a. Lay down any bad joints and replace with new. 26. MU packer mill BHA and TIH with 3-1/2" PH-6 workstring to the tubing stub at+/-5,398' md. 27. Establish milling parameters, burn over packer. TOOH. a. Once burned over, the packer should drop^'3' onto the liner top. 28. MU overshot/jar BHA and TIH to latch packer. POOH w/packer. 29. RU EL unit and RIH w/6" gauge ring to tag Baker Flex Lock Hanger at 5,540' md. 30. MU CBL and log 7" casing from 5,540'-4,400' md. a. Process log and send to Ops Engineer for review as soon as possible. 31. POOH and RD E-Line unit. 32. MU completion per the proposed schematic, consisting of: a. 4-1/2" WLEG • RWO Revision#1 • Well: KTU 32-07 nikoii' la-la,1'1` Date: 10/26/2016 b. 4-1/2" pup joint c. 4-1/2" X nipple (ID=3.813"). RHC plug body to be installed in nipple profile before TIH. d. 4-1/2" pup joint e. 4-1/2" pup joint f. 4-1/2"x7" Packer g. 4-1/2" pup joint h. 4-1/2" X nipple (ID=3.813") i. 4-1/2" pup joint j. 4-1/2" tubing joint k. 4-1/2" GLM I. 4-1/2" pup joint m. 4-1/2" tubing to surface 33. RIH with 4-1/2" completion to place WLEG at+/-4,910' md. 34. Obtain accurate pick-up and slack-off weights and record same. 35. Land tubing in hanger and pressure test void. 36. Drop ball and rod and set packer as per service rep guidelines. 37. Pressure test tubing to 3000psi for 30 min. Bleed off pressure post passing test. 38. Pressure test the 4-1/2"x7" annulus to 2500psi for 30 min. Bleed off pressure post passing test. 39. Set BPV. ND BOPE. NU 4-1/16" 5M tree. Pull BPV. 40. Set TWC.Test tubing hanger and tree to 250/5,000 psi. Pull TWC. 41. RD Moncla #401 WO Rig. 42. Replace IA x OA pressure gauge if removed (4-1/2"x7") and (7"x9-5/8"). Slickline Procedure: 43. MIRU Slickline, Pressure test to 250psi low/2500psi high. 44. RIH and pull the ball & rod, and the RHC plug body from x nipple @ +/-4,900' md. 45. RD Slickline. Coil Tubing Procedure: 46. MIRU Coil Tubing Unit. Pressure test to 250psi low/4500psi high. 47. RIH w/ 1.5" coil to 7,260' and to the top of cement on the 4-1/2" plug. C" 48. Begin reverse circulating N2 down the CTxTbg annulus while taking returns up the coil to displace wellbore fluids to nitrogen. a. 4-1/2" tubing volume to WLEG (0.0152bpf x 4,910') = 75bbls b. 7" casing from WLEG to 7" CIBP (0.0371bpf x 630') =24bbls c. 4-1/2" tubing volume from lower packer to plug (0.0152bpf x 1720') = 27bbls d. Total volume to be returned = 126bbls ./ 49. POOH with coil and RD Coil Tubing Unit. E-Line Procedure: 50. MIRU E-Line unit. Pressure test to 250psi low/2500psi high. 51. MU perf guns and perforate the following intervals: Zone Sand Bottom Shot (md) Top Shot(md) Ft +1-6458 +/-7225 Upper Beluga UB-7 +1-5464 +/-5523 59 Upper Beluga UB-5 +/-5336 +/-5428 92 Upper Beluga UB-3 +/-5162 +/-5219 57 Upper Beluga UB-1 +/-5034 +1-5074 40 • RWO Revision#1 • Well: KTU 32-07 Hilcorp Alaska,Lb Date: 10/26/2016 Upper Beluga UB-X +/-4989 +/-4995 6 a. Bleed surface pressures down as per Ops Engineer. b. Confirm with Ops Engineer final correlation log prior to perforating. c. Record pre/post perforating tubing pressures in the daily report. 52. RD E-Line unit. 53. Turn well over to production. E-line Procedure (Contin enc :If any zone produces sand and/or water and cannot be swabbed down with Slickline. 54. MIRU E-Line unit. Pressure test to 250psi low/4000psi high. 55. RU nitrogen pumping unit and connecting hoses. PT equipment to 5,000 psi Hi 250 Low (Review Standard Well Procedure—Nitrogen Operations with all personnel on site). 56. Pressure up well with nitrogen to push water away. Injection pressure should be around 4,000 psig. Once injection pressure has stabilized, stop pumping and SI well. 57. RIH with Pressure/Temperature tool and check for fluid level. POOH. 58. If fluid isn't completely pushed away, pump more nitrogen until water is below 5,000'. 59. RD nitrogen pumping unit. 60. MU 4-1/2" expandable plug (SLB Posi-set, petal basket, HES TTBP or similar) and setting tool. a. If top of fill is close to the perfs, cement may be placed on top of fill. 61. RIH and set expandable plug within +/-10' of top perf. POOH w/setting tool. 62. MU dump bailer and place 10' cement cap on top of plug. 63. Wait a minimum of 24 hours for cement to set. 64. Manipulate the SITP to match the requested drawdown on the formation. a. This to be confirmed with RE prior to perforating. 65. MU and RIH w/2-7/8"—3-3/8", 60 deg phasing guns and perforate the next sand. 66. RD E-Line unit. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Actual Wellhead Diagram 4. Proposed Wellhead Diagram 5. Moncla 401 BOPE Schematic 6. CT BOPE Schematic 7. CT Schematic(forward and reverse jetting) 8. Blank RWO Procedure Change Form 0 • Kenai Gas Field • Et Well: KTU 32-07 SCHEMATIC Last Completed: 1/04/2001 llilcorp Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' 1.1 9-5/8" Surface 7" Intermediate 40/L-80/N/A 8.835 Surface 1,510' 23/L-80/N/A 6.366 Surface 5,040' 29/P-110/N/A 6.184 5,040' 5,690' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' �r TUBING DETAIL 3sM t ' 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' Max Inclination JEWELRY DETAIL 28.74'@ 2,771' J No Depth ID Item s 2 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel 2 5,007' 3.833 4-1/2"GL Mandrel 0 "3 3 5,400' 3.875 Baker 5-3 Packer above tied into liner top w/o seals 4 5,499' 3.813 Otis X nipple 5 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR 4 6 7,540' N/A CIBP 7 7,596' N/A CIBP Capped with 25'Cement C -.ftp 8 9,050' N/A HES Gun Hangar 9 9,074' N/A HES 10K EZ Drill ? 144 5 '' PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT SPF Date Status LB-4B 7,293' 7,313' 6,825' 6,845' 20 6 08/18/2015 Open 7" LB-4D _ 7,376' 7,390' 6,908' 6,922' 14 6 08/18/2015 Open LB-5B 7,495' 7,515' 7,027' 7,047' 20 6 08/18/2015 Open T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 01/09/2001 Partially Covered T 73-1 7,703' 7,710' 7,234' 7,241' 7' 6 01/09/2001 Covered 4' T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 01/09/2001 Covered T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 01/09/2001 Covered T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 09/29/2000 Covered T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 09/13/2000 Covered 1848 CEMENTING DETAIL LB-40 Casing Detail LB-6B 9-5/8" 12-1/4"hole w/400sks of cement *, 7" 8-1/2"hole w/445sks of cement 6 4-1/2" 6-1/8"hole w/675sks of cement t r 7 TOFQE.191'314f14dry ',s poky bah dsend 'y,; 1, ,. Fir.9.*Faker Hyd -' 0lscomed 3 . "E Prop Frac'd perfs w/21,6941bm of , 4linVMod1 Iloior ,,,� 4 carbonate using gelled diesel-11/14/2000 Ileldr'4 BladedMAU `�- K • 1ES10KFAS DrN `.7''r. `C P g ! I I 1 t,'I ' 14 a y '4 9 TD=9,117'/PBTD=9,047' Updated by DMA 09-18-15 ,11 0 0 Kenai Gas Field Well: KTU 32-07 PROPOSED SCHEMATIC Last Completed: 1/04/2001 Hiker!) alai a.II(' API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' 7" Intermediate 23/L-80/N/A . 6.366 Surface 5,040' 13-s/s" L 29/P-110/N/A 6.184 5,040' 5,690' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' TUBING DETAIL ss/g I , 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' rMax Inclination JEWELRY DETAIL 28.74°@ 2,771' 2 No Depth ID Item k'3 1 +/-4,810' 3.833 4 L/2"GL P:landrel 2 +/-4,860' 3.813 ),(4 Nipple ` 4 3 +/-4,880' 3.875 4-1/2"x7"Perm Packer aim/ 4 5 4 +/-4,900' 3.813 X nipple 5 +/-4,910 3.995 WLEG '.-so' 6 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR 7 +/-7,270' N/A 4-1/2"CIBP Capped with 25'Cement 8 7,540' N/A CIBP 9 7,596' N/A CIBP Capped with 25'Cement 10 9,050' N/A HES Gun Hangar 4i 11 9,074' N/A HES 10K EZ2"CIBIt 44, iw,, PERFORATION DETAIL y1. F( 6 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status *ef C1144 . j UB-X +/-4989 +/-4995 Future r,' UB-1 +/-5074 +/-5034 Future UB-3 +/-5219 +/-5161 Future UB-5 +/-5428 +/-5336 Future 1 UB-7 +/-5464 +/-5523 Future p LB +/-6458 +/-7225 Future LB-4B 7,293' 7,313' 6,825' 6,845' 20 6 08/18/2015 Isolated I. . LB-4D 7,376' 7,390' 6,908' 6,922' 14 6 08/18/2015 Isolated i ,� LB-5B 7,495' 7,515' 7,027' 7,047' 20 6 08/18/2015 Isolated T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 01/09/2001 Isolated i T 73-1 7,703' 7,710' 7,234' 7,241' 7' 6 01/09/2001 Isolated 7 ?? T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 01/09/2001 Isolated T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 01/09/2001 Isolated LB 4B T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 09/29/2000 Isolated LB 4D T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 09/13/2000 Isolated LB-5B 8 � 8 TOF @ 8,191'3/4/14 dry >r i paddy balls of sand .>,t 9 Fish:09,022 *Baker Hyd.Discorned *Grculating Valve *Navidril Mach 1 Motor *4 Bladed Junk MII 'FES10KFASCrill _ Prop Frac'd perfsw/21,6941bm of CEMENTING DETAIL *Composite Plug ,,t .` carbonite using gelled diesel-11/14/2000 hal In ''10 Casing Detail 4-1/2" �. • _'11 9-5/8" 12-1/4"hole w/400sks of cement 7" 8-1/2"hole w/445sks of cement TD-9117/PBTD-9047 4-1/2" 6-1/8"hole w/675sks of cement Updated by DMA 09-18-15 S S Kenai Gas Field KTU 32-07 Hileerp Alaska.LI t 02/13/2013 Kenai Gas Field KTU 32-07 Tubing hanger,MB-150,11 X 13 3/8 X 9 5/8 X 7 X 4 1/2 4.909 MCA lift X4'/:IBT susp, w/4"TypeH BPVprofil2- 'A continuous control lines 6.5"Extended neck Tree cap,Otis,4 1/16 5M FE X 6%Otis Quick Union gl ami alai O, �\ iA nes`� �, •$/4°' , \C,%' <c�(''�`.((` Valve,Swab, .14' <, h� O VG-230,41/16 5M FE,HWO, e a\�e'�`'.6 ,a��y\des O DD trim iti.` J , Ops �' p. — Tee,stdd,4 1/16 5M X ■ C 3 1/8 5M { I •4 t*4 ° Nowin lm.... Valve,upper master, ;i`.S' VG-230,4 1/16 5M FE,HWO, 1I • DD trim 1 7'Iw N Valve,master, ta�, '\ VG-230,4 1/16 SM FE,HWO, DD trim *' 4,1111010 'Pill= Adapter,Vetco,11 5M stdd X 4 1/16 5M stdd top,prepped f/6.5"extended neck hanger Multibowl,Vetco MB-150, _ — 11 3M stdd bottom X ' �� IlliiE:=11 5M FE top,w/ ~ ~' 2-2 1/16 5M 550,1 control line exit J m - e ? 1 f Starting head, ij,IiI Vetco MB-150, 11 3M X95/8 SOW bottom, w/2-2"LPO IMO lee II 1113 3/8" 9 5/8" 7" 4.5" • • Kenai Gas Field KTU 32-07-Proposed 10/28/2016 Ililrurp Kenai Gas Field KTU 32-07 Tubing hanger,MB-150,11 X 133/8 X 95/8X 7 X 4 1/2 4.909 MCA lift X4'''AIBTsusp, w/4"Type H BPV profile,2- 'A continuous control lines 6.5"Extended neck Tree cap,Otis,4 1/16 SM FE X 6'A Otis Quick Union > 0 t uuai_uno 1111 ,Z <A> QF''e Valve,Swab, "4.k \cb WKM M,41/16SM FE, ‘•J� n� QO ��e�g� F J SQe�� HWO, DD trimw L' Q,o U ‘-‘\‘ SASS O MI m m is PAL-, , Tee,stdd,4 1/16 5M X C 71, 31/85M O U11I J Valve,upper master, 04. lob C+y WKM-M,4 1/16 5M FE, v; HWO, DD trim U rrn Valve,master, 4• G WKM-M,41/16 SM FE, ~! fie4 HWO, DD trim G v` unci min Adapter,Vetco,11 5M stdd X 4 1/16 5M stdd top,prepped f/6.5"extended neck hanger 111 Multibowl,Vetco MB-150, rmii411111111. 11 3M stdd bottom X 11 5M FE top,w/ 2-2 1/16 SM SSO,1-control line exitJ `g a:h Ai I . r Starting head, Vetco MB-150, I�*' sE0 11 3M X 9 5/8 SOW bottom, [Milli w/2-2"LPO 13 3/8" 195/8" 7" 4.5" • • • . 11 KGF—KTU 32-07 2016 Moncla Rig#401 Knight Oil Tools BOP Hilrorp:dark■,tic ( 1 O O It fro fril fril in] t1 HYDRIL 11"5M i I iii iii iii 1i1 I!! iii LE 1i1 Lit \ 2-7/8 x 5"variable CAMERON I P N 10.5' H _ O p H 1 '� O O ' 111 / _ ,� O !' 1 f N. Blind H 0 0 =' DSA O . / 4-1/6"5M x 2-1/16" 10M 1] in Mai ,f 1 \\\_,.•\_ Choke and Kill valves are 2-1/16 10M — 4,(-t ' 0.114..)11 1 . 0011. _ _ , ' *IP &) J *(rivii 3 iurko i • , , ..il ,- ,. ., 4-* i 40 -1-31-rirtin-Hfl-finv 1] "t* . -5 - (.- t .__,_, HCR 11" 5M Drilling Spool w/one 4-1/16"5 M Outlets • . . IIKenai Gas Field KTU 32-07 10/26/2016 11.14 orp 11n-Iia,LL(: Coil Tubing BOP Lubricator to injection head ) 0 i I p 1 .5' Tandem Stripper _1 I 4111610M C_ - [ Blind/Shear Blind/Shear : J / — I — j1 - Blind/Shear Blind/Shear _1 L = slip Imo Slip liii. ' 1 C i Mud Cross Q- = — — Pipe Pipe : I___ C II ----\\ 4 1/16 10M X 4 1/16 10M Outlet w/ 2- 2 1/16 10M full r opening FMC valves - _ - ` ; 111 Mme : m : .,- ;. ,.. 0 101 to H. , I a_ III« gni a i : Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M a • . . 81 s ,7 D Y D co a k ,1 Q z Y ] U 7 Q El o Y .] 0 Z o o k U D At ►•• , 3 -H+ 3E E3 Mg i I V V • N I 88 k 1111,llll1 i N= Z j 411 004 I L. s c , O a` 0 L in I,I III,� — imilIi ® lilill■1h SISI4 j O) 0 19 111(-5 Z c 0 r co_ 0 r d • o I I II I IO ,.k :._17- .t 8 E ki 0 11 • = c cm c .s O n E O O U Z O 0 g t k r� • • z8j • Z 9 . 1 � 7]J 1 I— Z N 3� CO O 1 O o F C U - CC-.) Ail 1004•4 p G 3313 Q I. Digs c, L • D - 3 iimi c Logii N Z N '0, (n 0c_ C L Un Z 0 O a` '1.2 I�I I' IIII III .x —.I111 ® 1II'!II■N'.�iSI , 4 , •11 lc III Ill a a N if ; Y c O H n 0 1- , : 1 A ce V • A ;ill .O 6 k 5 c il rn n n c c f O n v w U N O Z OS O A L k Z 1 0 0 � t0 �f 2>, o as e c 7 / 02e / 0 2 �� gf E ® Ec -a � k Yk § : § z a. c » CI < a" - k / 0 CO ■ 7 -0 x0c �.§ a 0E § : n -0 a) a) 2 . .1 ■ z k k � co§ a) >- 0 co co Zet a ff $ 0 n t 76 c -0 J o >. CDa) VS k � Y gf » a) % U ■ IE� « a).c 2 E Zr) C.) I = = m 2 2o ' "C I- .0 ti a) a) .Ca c k C) (/) k0 c 2 > k2 0 § o 0. fta « CO 0 0 0. ta x co3 a) 2 a » & co ; I 0 Isi *a § / $ W a g 0 > Q il 0 ELI art, .. . •• � U ) E 0 a) ' c c 0 ® a r Cl)Z3 Co) co k 9 U) • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, November 21, 2016 9:31 AM To: Taylor Wellman Subject: RE: Kenai Gas Field well KTU 32-07 (PTD#200-023/API#501332049100) RWO Sundry #316-574 Change Request Taylor, The addition perf intervals are out of the approved ND area. A change of program sundry will be needed. We can expedite the sundry as the holiday weekend is fast approaching. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Taylor Wellman [mailto:twellman@hilcorp.com] Sent: Friday, November 18,2016 11:34 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject: Kenai Gas Field well KTU 32-07(PTD#200-023/API#501332049100) RWO Sundry#316-574 Change Request Guy, For the Kenai Gas Field well KTU 32-07(PTD#200-023/API#501332049100)we recently received approval for a RWO in Sundry#316-574. Since this time we were able to locate an additional hard copies of logs that our digital log files were corrupted. The hard copies were found in another well's wellfile. The outcome of reviewing these logs has shown additional targets that we would like to add to the sundry to perforate. Note that these new perf intervals are all in the Lower Beluga and are in the same pool as both existing and other proposed perfs. Changes to the approved sundry(found in red in the attached revised procedure): - 1.Slickline Prep-Updated for slickline drift that was completed. - 6. E-Line Prep-Set 4-1/2" CIBP (isolation of current perforations) 10'deeper&closer to the current top perf. - 31. Rig-Remove this step to set a 7" CIBP in the casing. - 47.Coil Tubing Post—Jet well dry from deeper plug vs.the previous 7" plug. - 51. E-Line Post—Increased perf intervals in the Lower Beluga. We will be providing copies of the logs as we get them digitized to you as well. Please review and let me know if you have any questions/concerns with this change. If approved I will update the Sundry Change Form. Thank you, Taylor Taylor Wellman 1 • • Hilcorp Alaska, LLC RECEIVEDI V Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive NOV 2 1 2016 Suite 100 Anchorage,AK 99503 November 21, 2016 AOGCC Mr. Guy Schwartz Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: KTU 32-07 (PTD 200-023) Sundry 316-574 Change Dear Mr. Schwartz: Hilcorp would like to cancel or withdrawal Sundry #316-574 for the rig workover on Kenai Unit Well KTU 32-07 PTD 200-023 and re place with the attached 10-403 sund re.uest. This new application has additional perfs and removed a CIBP from the program. We anticipate starting this wellwork with the Moncla rig November 25th Should you have any additional questions, please contact Chad Helgeson (777-8405 or chelgeson@hilcorp.com) or Taylor Wellman(777-8449 or twellman@hilcorpcom) Sincerely, HILCORP ALASKA, LLC SCAt4NW APR 2 8 201Z Chad A Helgeson Operations Manager 10-403 application request RBDMS Lt..- j262017 • • V OF Tyt *.Q ��//j,1,v THE STATE Alaska Oil and Gas ,�� Of�T /� SKA Conservation Commission rF== 333 West Seventh Avenue " " GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wR Main: 907.279.1433 ;SYS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson ` Operations Manager �o vAp �'�� Hilcorp Alaska, LLC Ste* 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Kenai Field, Beluga/Upper Tyonek Gas Pools, KTU 32-07 Permit to Drill Number: 200-023 Sundry Number: 316-574 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, Daniel T. Seamount,Jr. Commissioner DATED this �d day of November, 2016. RBDMS Nur/ 1 6 2016 • • RECEIVED • STATE OF ALASKA NOV 0 4 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations ❑✓ , Fracture Stimulate 0 Repair Weil ❑ Operations shutdown❑ Suspend ❑ Perforate Q ' Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Complete Up Hole_Q 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. N= Ds f.:.,_, ...ac. Exploratory ❑ Development ❑✓ 200-023 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20491-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 510a ' Kenai Tyonek Unit(KTU)32-07- Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): A-028142 • Kenai Gas Field-Beluga/Upper Tyonek Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft):/ Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): qin. 8,648' 9,047' 8,578' Pre 957psi;Post 1,780psi 7,540';7,596' 8,191'(fill) Casing /, Length Size MD TVD Burst Collapse Structural Conductor 123' 13-3/8" 123' 123' 3,090 psi 1,540 psi Surface 1,510' 9-5/8" 1,510' 1,509' 5,750 psi 3,090 psi Intermediate 5,040' 7" 5,040' 4,717' 6,340 psi 3,830 psi Intermediate 650' 7" 5,690' 5,294' 11,220 psi 8,530 psi Liner 3,577' 4-1/2" 9,117' 8,548' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 5,540' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): S-3&ZXP Packer and N/A 5,400'MD/5,036'ND&5,540'MD/5,160'ND and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: November 17,2016 OIL ❑ WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Q ' WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman-777-8449 Email twellman@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature NA"; A I ryk CA Phone 907-777-8405 Date ///3 r COMMISSION USE ONLY Conditions of approval: N:ify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4i 2,500 13S:. 6C:77 I t., fr 4.... "-- It lit, [6 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes El No Subsequent Form Required: 1 0 — 1C)41 RBDMS Z,L NOV1 6 2016 APPROVED BY /0 /4-- o iib Approved by: A COMMISSIONER THE COMMISSION Date: l// / rSubmit Form and Form 10-40 evised 111/2;157'!t Rrt, d c IAs valid for 12 months from the date of approval. Attachments in Duplicate 44 • d_: /7 7 4- • • RWO Well: KTU 32-07 Hiicorp Alaska,LL' Date:10/26/2016 Well Name: KTU 32-07 API Number: 50-133-20491-00 Current Status: Online Gas Well Leg: N/A Estimated Start Date: 11/17/16 Rig: Moncla 401 / Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-023 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907)229-4824 (M) AFE Number: Current Surface Pressure: 65 psi Maximum Expected BHP (Current): 1620 psi @ 6,825' TVD Max. Potential Surface Pressure (Current): 957 psi (0.1 psi/ft to surface) Maximum Expected BHP (Post add UB-7): 2290 psi @ 5,093' TVD Max. Potential Surface Pressure(Post add UB-7): 1780 psi (0.1 psi/ft to surface) Brief Well Summary Kenai Tyonek Unit 32-07 (KTU 32-07) is a Tyonek producer drilled in 2000 with the perforated interval ranging from the Tyonek 72-8 sand at 7652' MD to the Tyonek 86-2 sand at 9042' MD. Since the beginning of production this interval has had problems staying above the critical velocity to keep the well unloaded. Water • production began at small rates (<1BWPD) initially but increased to 10 BWPD within the first two years of production. The completion is a 4.5" monobore with a chemical injection mandrel at 2099' and a gas lift mandrel at 5007'. The well was able to produce above the unloading rate briefly in 2003 but was unable to maintain this rate. A SBHP measured on 7/7/2010 showed the formation has 1320 psi. On 9/08/2013 operators attempted to flow the well. Sand production filled the tubing to above the top perf with the last tag • at 6467'SLM on 9/22/2013.The well was cleaned out to 8,191' CTM in March 2014 using coil tubing. A planned velocity string in 2014 was never installed. The purpose of this work/sundry is isolate the existing perforations and to recomplete the well uphole to allow . for production from the UB-7, UB-5, UB-3, UB-1, and UB-X sands. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people • could enter, i.e. near flow-back tank. • Consider tank placement based on wind direction and current weather forecast(venting methane and Nitrogen during this job) • Ensure all crews are aware of stop job authority Pre-Sundry Operations Slickline Procedure: 1. MIRU Slickline, pressure test lubricator to 250psi low and 2000psi high. 2. MU 3.625" dummy plug toolstring and drift past 7,250' md. a. This drift will work for the deepset CIBP and the tubing cutter to be used at a later step. 3. RD Slickline unit. Sundried Operations—All operations beyond this point will require the approved sundry E-Line Procedure: 4. MIRU E-Line unit. Pressure test to 250psi low/2000psi high. 5. MU 4-1/2" CIBP toolstring. . • • RWO Well: KTU 32-07 Ilikurp Alaska,LU Date: 10/26/2016 6. RIH and set CIBP at+/-7,250' md. POOH. 7. Dump 25' (16.0 gal) ofcement on top of the CIBP. 8. MU and RIH w/4-1/2" tubing puncher. y 9. Use CCL to correlate and punch tubing from +/-5406'to+/-5408' md. a. This is in the mid pup joint below the packer. 10. POOH and RD E-Line unit. Pumping Procedure: 11. Load tubing with 3% KCI (8.5ppg). a. Tbg FL shot @ 2880' and on 11/2/16: 4-1/2" Tubing volume to 4-1/2" CIBP (0.0152bpf x 2,880') =44bbls b. IA FL shot @ 1883' on 11/2/16:4-1/2"Tubing x 7" annular volume below packer (0.0175bpf x 1,883') = 33bbls c. Total =77bbls 12. Pressure test the plug to 1500psi. 13. Bleed down tubing pressure to"200psi upon test completion. 14. Load IA with with 3% KCI (8.5ppg). E-Line Procedure: 15. RU E-Line unit and pressure test to 250psi low/2000psi high. 16. RIH and tag cement top. 17. MU and RIH w/4-1/2" chem cutter. Oa. 18. Chem cut tubing at+/-5,3981'md (mid pup joint directly above the packer). a. Correlate to the KTU 32-07 tubing tally. b. Ensure tubing pressure is above IA pressure prior to cut. c. Note pressure equalization in report after cut. 19. RD E-Line unit. WO Rig Procedure: 20. MIRU Moncla #401 WO Rig. 21. Confirm tubing pressure is Opsi. 22. Set 4" BPV. ND Tree. 23. NU 11" BOPE. Pull BPV. Set TWC. Test to 250 psi Low/2,500 psi High, annular to 250 psi Low/ 11-500-psi High (hold each valve and test for 5-min). Rei ulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8" test joint. 24. Bleed any pressure off tubing. Pull TWC. 25. Pull 4-1/2"tubing and rack back joints as needed down to the tubing cut at+/-5,398' md. a. Lay down any bad joints and replace with new. 26. MU packer mill BHA and TIH with 2-7/8" PH-6 workstring to the tubing stub at+/-5,398' md. i3Alit 27. Establish milling parameters, burn over packer. TOOH. ti P� a. Once burned over,the packer should drop"'3'onto the liner top. 28. MU overshot/jar BHA and TIH to latch packer. POOH w/packer. 29. RU EL unit and RIH w/6"gauge ring to tag Baker Flex Lock Hanger at 5,540' md. 30. MU CBL and log 7" casing from 5,540'-4,400' md. L. a. Process log and send to Ops Engineer for review as soon as possible. �� 31. MU 7" CIBP and RIH to set at 5,535' md. 32. POOH and RD E-Line unit. 33. MU completion per the proposed schematic, consisting of: . • • RWO Well: KTU 32-07 !carp Alaska.LL) Date: 10/26/2016 a. 4-1/2" WLEG b. 4-1/2" pup joint c. 4-1/2" X nipple (ID=3.813"). RHC plug body to be installed in nipple profile before TIH. d. 4-1/2" pup joint e. 4-1/2" pup joint f. 4-1/2"x7" Packer g. 4-1/2" pup joint h. 4-1/2" X nipple (ID=3.813") i. 4-1/2" pup joint j. 4-1/2"tubing joint k. 4-1/2" GLM I. 4-1/2" pup joint m. 4-1/2" tubing to surface 34. RIH with 4-1/2" completion to place WLEG at+/-4,910' md. 35. Obtain accurate pick-up and slack-off weights and record same. 36. Land tubing in hanger and pressure test void. 37. Drop ball and rod and set packer as per service rep guidelines. A- 38. Pressure test tubing to 3000psi for 30 min. Bleed off pressure post passing test. ON-4.AX 39. Pressure test_the 47112"x7" annulus to 2500p5i for 30 min. Bleed off pressure post passing test. 40. Set BPV. ND BOPE. NU 4-1/16" 5M tree. Pull BPV. y Cho,,cf 41. Set TWC.Test tubing hanger and tree to 250/5,000 psi. Pull TWC. 42. RD Moncla#401 WO Rig. 43. Replace IA x OA pressure gauge if removed (4-1/2"x7") and (7"x9-5/8"). Slickline Procedure: 44. MIRU Slickline, Pressure test to 250psi low/2500psi high. 45. RIH and pull the ball & rod, and the RHC plug body from x nipple @ +/-4,900' md. 46. RD Slickline. Coil Tubing Procedure: 47. MIRU Coil Tubing Unit. Pressure test to 250psi low/4500psi high. 48. RIH w/1.5" coil to 5,530' and to top of 7" plug. 49. Begin reverse circulating N2 down the CTxTbg annulus while taking returns up the coil to displace wellbore fluids to nitrogen. .q6/1) t 0 a. 4-1/2" tubing volume to WLEG (0.0152bpf x 4,910' md) = 75bbls VP/ b. 7" casing from WLEG to 7" CIBP (0.0371bpf x 530' md) = 20bbls V `'e c. Total volume to be returned = 95bbls 50. POOH with coil and RD Coil Tubing Unit. --- E-Line Procedure: 51. MIRU E-Line unit. Pressure test to 250psi low/2500psi high. 52. MU perf guns and perforate the following intervals: Zone Sand Bottom Shot (md) Top Shot (md) Ft Upper Beluga UB-7 +/-5464 +/-5523 59 • /�'S Upper Beluga UB-5 +/-5336 +/-5428 92 Upper Beluga UB-3 +/-5162 +/-5219 57 Upper Beluga UB-1 +/-5034 +/-5074 40 Upper Beluga UB-X +/-4989 +/-4995 6 • • RWO Well: KTU 32-07 Ililcarp Alaska,LL Date:10/26/2016 a. Bleed surface pressures down as per Ops Engineer. b. Confirm with Ops Engineer final correlation log prior to perforating. c. Record pre/post perforating tubing pressures in the daily report. 53. RD E-Line unit. 54. Turn well over to production. E-line Procedure (Contingency):If any zone produces sand and/or water and cannot be swabbed down with Slickline. 55. MIRU E-Line unit. Pressure test to 250psi low/4000psi high. 56. RU nitrogen pumping unit and connecting hoses. PT equipment to 5,000 psi Hi 250 Low(Review Standard Well Procedure—Nitrogen Operations with all personnel on site). 57. Pressure up well with nitrogen to push water away. Injection pressure should be around 4,000 psig. Once injection pressure has stabilized, stop pumping and SI well. 58. RIH with Pressure/Temperature tool and check for fluid level. POOH. 59. If fluid isn't completely pushed away, pump more nitrogen until water is below 5,000'. 60. RD nitrogen pumping unit. 61. MU 4-1/2" expandable plug(SLB Posi-set, petal basket, HES TTBP or similar) and setting tool. a. If top of fill is close to the perfs, cement may be placed on top of fill. 62. RIH and set expandable plug within+/-10' of top perf. POOH w/setting tool. 63. MU dump bailer and place 10' cement cap on top of plug. 64. Wait a minimum of 24 hours for cement to set. 65. Manipulate the SITP to match the requested drawdown on the formation. a. This to be confirmed with RE prior to perforating. 66. MU and RIH w/2-7/8"—3-3/8", 60 deg phasing guns and perforate the next sand. 67. RD E-Line unit. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Actual Wellhead Diagram 4. Proposed Wellhead Diagram 5. Moncla 401 BOPE Schematic 6. CT BOPE Schematic 7. CT Schematic(forward and reverse jetting) 8. Blank RWO Procedure Change Form • H • 0 Kenai Gas Field Well: KTU 32-07 SCHEMATIC Last Completed: 1/04/2001 Hileorp Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AG1=21' Size Type Wt/Grade/Conn ID Top Btm k; 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' frro 23/L-80/N/A 6.366 Surface 5,040' 13-3,S- f 7" Intermediate 29/P-110/N/A 6.184 5,040' 5,690' 4' 4 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' v TUBING DETAIL 9sM'1 a. t",1 i 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' Max Inclination 4 JEWELRY DETAIL 28.74`@ 2,771' Pi No Depth ID Item •2 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel 1,- riN - 2 5,007' 3.833 4-1/2"GL Mandrel �� 3 5y ca 3 5,400' 3.875 Baker S-3 Packer above tied into liner top w/o seals 4 5,499' 3.813 Otis X nipple 5 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR ..., 4 6 7,540' N/A CIBP 7 7,596' N/A CIBP Capped with 25'Cement 8 9,050' N/A HES Gun Hangar 4 G� 9 9,074' N/A HES 10K EZ Drill t 4t PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Date Status 4' LB-4B 7,293' 7,313' 6,825' 6,845' 20 6 08/18/2015 Open T` ` '' LB-4D 7,376' 7,390' 6,908' 6,922' 14 6 08/18/2015 Open LB-5B 7,495' 7,515' 7,027' 7,047' 20 6 08/18/2015 Open T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 01/09/2001 Partially • ,, Covered ^" T 73-1 7,703' 7,710' 7,234' 7,241' 7' 6 01/09/2001 Covered -,t, iii T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 01/09/2001 Covered T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 01/09/2001 Covered T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 09/29/2000 Covered T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 09/13/2000 Covered tags CEMENTING DETAIL L841) IE Casing Detail LB-5B 9-5/8" 12-1/4"hole w/400sks of cement }t A, 7" 8-1/2"hole w/445sks of cement r l 184 rtr 6 4-1/2" 6-1/8"hole w/675sks of cement 7 TOF68.191'314114dy '`,° pudgy beb d tend y; 1' r 5. Fick O/422: ,1 ' ar Veer Md Olekrnmect ', , Prop Frac'd perfs w/21,6941bm of 'CJrcuUWlrs gWw carbonite using gelled diesel-11/14/2000 "14188111 Mach 1 Mar II 3, `4 Bladed Junk MII `IES 10K FPS MI . .Rh � npaPlug $ Jq I 1 1. 1 8 9 TD=9,117'/MID=9,041 Updated by DMA 09-18-15 0 Kenai Gas Field . II • Well: KTU 32-07 PROPOSED SCHEMATIC Last Completed: 1/04/2001 Hilcora Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21' Size Type Wt/Grade/Conn ID Top Btm "' 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' ...:4, 9-5/8" Surface 7" Intermediate 40/L-80/N/A 8.835 Surface 1,510' S i; + 23/L-80/N/A 6.366 Surface 5,040' 133/8" :e ," 29/P-110/N/A 6.184 5,040' 5,690' *7 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' ' IO ., TUBING DETAIL,11 ;., , 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' . Max Inclination 1 JEWELRY DETAIL 28.74°@ 2,771' 2 I No Depth ID Item .$, 3 1 +/-4,810' 3.833 4-1/2"GL Mandrel 2 +/-4,860' 3.813 X Nipple : ,s, 4 3 +/-4,880' 3.875 4-1/2"x7"Perm Packer 5 4 +/-4,900' 3.813 X nipple 4.4 5 +/-4,910 3.995 WLEG r`� 1 6 +1-5,535' N/A 7"CIBP $j 7 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR No o1/4.6 8 +/-7,260' N/A 4-1/2"CIBP Capped with 25'Cement 9 7,540' N/A CIBP 10 7,596' N/A CIBP Capped with 25'Cement f 11 9,050' N/A HES Gun Hangar 12 9,074' N/A HES 10K EZ Drill ' -, ' 6 PERFORATION DETAIL 11 ` ; =' 7 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status ° UB-X +/-4989 +/-4995 Future ' UB-1 +/-5074 +/-5034 Future ,a v UB-3 +/-5219 +/-5161 Future • `i:.�i � � UB-5 +/-5428 +/-5336 Future yea S�cIC*. UB-7 +/-5464 +/-5523 Future tea T' :74 LB-4B 7,293' 7,313' 6,825' 6,845' 20 6 08/18/2015 Isolated ' e a Ps LB-4D 7,376' 7,390' 6,908' 6,922' 14 6 08/18/2015 Isolated *! LB-5B 7,495' 7,515' 7,027' 7,047' 20 6 08/18/2015 Isolated 1 T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 01/09/2001 Isolated i4110 " 8 T73-1 7,703' 7,710' 7,234' 7,241' 7' 6 01/09/2001 Isolated .a` LB-4B T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 01/09/2001 Isolated T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 01/09/2001 Isolated eZ LB-4D T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 09/29/2000 Isolated , " T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 09/13/2000 Isolated LB-5B 9 r 1 ` ; '1 10 TOF @ 8,191'3/4/14 dry L puddy balls of sandFish:09,02Znn *Baker Hyd.Discoect , *Circulating Valve f :,, *Navidril Mach 1 Motor *4 Bladed Junk Mill ,' . 1-ES10KFAS LBII 1 • Prop Frac'd perfs w/21,6941bm of CEMENTING DETAIL Composite Plug 14. ".* ,AA carbonite using gelled diesel-11/14/2000 c i 11 Casing Detail 4-1/2" . ,,. ':. 1 r 12 9-5/8" 12-1/4"hole w/400sks of cement 7" 8-1/2"hole w/445sks of cement TD=9,117/PBTD=9,047 4-1/2" 6-1/8"hole w/675sks of cement Updated by DMA 09-18-15 Kenai Gas Field , ll KTU 32-07 02/13/2013 Iliinlrp U:vkn,1.1,A. Kenai Gas Field KTU 32-07 Tubing hanger,MB-150,it X 13 3/8 X 95/8 7 X 4 1/2 4.909 MCA lift X4'A IBT susp, Xw/4"Type H BPV profile,2- 'A continuous control lines 6.5"Extended neck Tree cap,Otis,4 1/16 5M FE X 6''A Otis Quick Union 1 o IS,Ir1�11i1151 II III.-. ,t� o% ttk''.\F Valve,Swab, VG-230,4 1/16 SM FE,HWO, It ,.h ��e, „.,4 a,,,e 4b ,..O DD trim •V0 ilv �o�1\OOtt` �4- 9-Q sk- •Fiji I& .4�ti �,r Tee,stdd,4 1/16 5M X 1 a PH )4 3 1/8 5M a , / 11111 �( ' /Ii A Valve,upper master, n, VG-230,4 1/16 5M FE,HWO, y 1 DD trim • 1 H Valve,master, ti<zoi-,VG-230,4 1/16 5M FE,HWO, _...4 DD trim '• .0 7.01107 Adapter,Vetco,11 5M stdd X ur4 1/16 SM stdd top,prepped f/6.5"extended neck hanger Multibowl,Vetco MB-150, — r — 11 3M stdd bottom X -".I I'�MI, I ll -"Ai". �`- 11 5M FE top,w/ 2-2 1/16 5M SSO,1-control line exit = �'�' 'f" 67.. . .1 _ Starting head, li., r _ Vetco MB-150, 11 3M X 9 5/8 SOW bottom, MEI [Milli w/2-2"LPO III I 1 I 1113 3/8" 9 5/8" 7" 4.5, 11110 • Kenai Gas Field KTU 32-07-Proposed n 1.,..,, v.,.1.1.r.►. 10/28/2016 Kenai Gas Field KTU 32-07 Tubing hanger,MB-150,11 X 13 3/8 X 9 5/8 X 7 X 4 1/2 4.909 MCA lift X4'A IBT susp, w/4"Type H BPV profile,2- 'A continuous control lines 6.5"Extended neck Tree cap,Otis,4 1/16 5M FE X 6''A Otis Quick Union 11111 MI NMI �0 44\ MIS-Z•um ' s k`.' .�' Valve,Swab, ii1, r.� O e. �h QO WKM M,4 1/16 5M FE, wi * r» 1 \y e Jm°�ti\ mss, HWO, DD trim ,. U' ''.. J ', Q Q G 4\'S ' `S'O sk- •!N_mis ,,6� S�,r 11 Tee,stdd,4 1/16 5M X 1 (07/.°0Q0 9 — J 3 1/8 5M i _- , G )_ i�\ j/ • ■I lig Valve,upper master, }� ,. "O4 WKM-M,4 1/16 5M FE, L" j, o HWO, DD trim J�t�14) N MEW m Valve,master, , O 0 WKM-M,4 1/16 5M FE, PJ,'""`i01 HWO, DD trim .mayv 0 v O IN 1i N �__ Adapter,Vetco,11 5M stdd X MP 4 1/16 5M stdd top,prepped f/6.5"extended neck hanger Multibowl,Vetco MB-150, .�.�,1.i I ail 11 3M stdd bottom X =■gym Iwr ■_ �� 11 5M FE top,w/ ,. 2-2 1/16 5M SSO,1-control ■ line exit �i - . ,il,.■.!0 . �� ( �° sig ! 4 Starting head, ' Vetco MB-150, i _ 11 3M X 9 5/8 SOW bottom, MIN Milli w/2-2"LPO II II 1113 3/8" X95/8" 117" 4.5" • • KGF—KTU 32-07 • H 2016 Moneta Rig#401 Knight Oil Tools BOP Flavor?:tlaska,l.l.t: 0 rfl (fill (I l rn in m HYDRIL 11"5M rill Cfl all rfl fit / l LET TT LWCU / _ 2-7/8 x 5"variable AMP CAMERON � �� 10.5' _�� Op 1 = ■mil 0 0 I ,� ,;, , O 5 ., Blind HIII4 O ..AP - . . . DSA 4-1/6"SM x 2-1/16" 10M Li ( t 41 itt illi Choke and Kill valves are 2-1/16 10M Kt 0 , -r fit, i/--'. (ie. ,, ' 1/ *, ? 1,' @t iii, ^ i iiilUIIIiI[t1iO1 Itl.III.t$Iiiil.1 i HCR 11" 5M Drilling Spool w/one 4-1/16"5 M Outlets • • Kenai Gas Field il KTU 32-07 10/26/2016 III 4)rp tli�+Ga.i.i.<: Coil Tubing BOP i Lubricator to injection head } 0 I I 1 .5" Tandem Stripper 1 l 1■',I, Blind/Shear = 1/16 10 Blind/Shear '■ .', .',I,)Blind/ShearBlind/Shear : J 9:, „,r„ ' a � . 1 = _— Slip Slip lilt JiiIi Pipeimmi Pipe 1I11• Mud Cross 4 1/16 10M X 4 1/16 10M Outlet 1111w/2- 2 1/16 10M full ■� opening FMC valves g : ' ( ] ll 111 IIII I( 1 0 )iiia Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M • • ! < i 8 I U D3 E ? = 1 .] Q U � N9 '3 z Q m o 1 .] •••• l•- y i] o C ] La z 4 {j O C g ., ►�1 V Z ! •N N, /�/� N LL - r-/ O - 5543 �./ • - LTy.SO] V 1 q a 01 V • C A 0 % -I--, z a N A N • Z % I V ►04 L 0 Li_ c o C U 3 O n. 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Q—:: v, x 0 3 0 2 _d 2 w ® CO C5 / f ®0 0 g o 0 co ® < . v .. •• : 0 E U co \ % 0 to 0_ Z1V U) CO Q Z U) RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM SSION SEP 1 8 2015 REPORT OF SUNDRY WELL OPERATIONSAOG CC 1.Operations Abandon U Plug Perforations U Fracture Stimulate LI Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Coil N2 ❑Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 200-023 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20491-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028142 Kenai Tyonek Unit 32-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field-Beluga/Upper Tyonek Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,117 feet Plugs measured 7,450;7,596 feet true vertical 8,648 feet Junk measured 8,191 (fill) feet Effective Depth measured 9,047 feet Packer measured 5,400&5,540 feet true vertical 8,578 feet true vertical 5,036&5,160 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 123' 13-3/8" 123' 123' 3,090 psi 1,540 psi Surface 1,510' 9-5/8" 1,510' 1,509' 5,750 psi 3,090 psi Intermediate 5,040' 7" 5,040' 4,717' 6,340 psi 3,830 psi Intermediate 650' 7" 5,690' 5,294' 11,220 psi 8,530 psi Liner 3,577' 4-1/2" 9,117' 8,548' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.61601007" INL°5;54b' U' • 5,150'ND Packers and SSSV(type,measured and true vertical depth) S-3&ZXP Pkr;N/A 5,40015,540'MD 5,036/5,160'ND 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-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 56 0 0 71 Subsequent to operation: 0 430 0 0 71 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑� Exploratory Development o Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ 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: 315-406 Contact Taylor Nasse Email tnasseta'�.hilcorp.com Printed Name Taylor Nasse Title Operations Engineer �// Signature 4 Phone 907-777-8354 Date // O��S ft Form 10 404 Revised 5/2015 '' -r�RBDMS" EP 2 2 2015 7.‘ SSubmit Original Only '�vl • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KTU 32-07 200-023 50-133-20491-00 7/10/15 8 18 15 Daily Operations: 07/10/2015-Friday Sign in at office. Mobe to location. PTW and JSA.Spot equipment and rig up lubricator. Pressure test to 250 psi low and 2,000 psi high. Attempt to run 3.75" GR and tools set down in coil hanger in tree.Take GR off and tools went thru hanger with largest OD of 3-1/8". Check and found out hanger has 3.38" ID. Decided to run GPT tool and take out coil hanger Monday. RIH with GPT tool, tie into dip log and tag fill at 7,658'. Logged out of hole. BHP was 1,866 psi with TP-480 psi. Found FL at 3,950'. Rig down lubricator and turn well over to field. 07/13/2015- Monday Sign in at office. Mobe to location. PTW and JSA. Remove coil hanger from tree. (Clint Chanley). PTW and JSA. Spot equipment and rig up lubricator. Pressure test against bottom master valve to 250 psi low and 2,500 psi high.That tested both tree and lubricator.TP-302 psi. RIH with 3.75" GR/junk basket,tie into PESI Press/Temp log and set down at 5,550' (flex lok hanger). Pick up and went thru. Did that several times and then went down and tagged at 7,658' (same depth as PIT tag 7-10-15). POOH. RIH w/3.71" CIBP and tie into PESI P/T log dated 7-10-15 down to 7,628'. Run correlation log up to 7,150'. RA marker at 7,200'. Send to town. Get ok to set plug at 7,640'. Set plug at 7,640' with 370 psi on tubing. Pick 30' and set down and tag plug. POOH. RIH w/3" x 30' dump bailer filled with cement and dump cement on top of plug at 7�640'.Y POOH. RIH w/3" x 30' dump bailer filled with cement and dump cement on top of plug at 7,640'. POOH. Total cement dumped 16 gal/25'.TOC est at 7,615'. Cement in place at 1730 hrs. Rig down lubricator and turn well over to field. Left cement samples at office. 07/16/2015-Thursday Meet at office. Mobe to location. PTW and JSA. Spot equipment, rig up lubricator and pressure test to 250 psi low and 1,500 psi high. RIH w/ 1-3/4" DD bailer and 3.70" cent to 7,651' KB. Work tools to 7,664' KB. POOH. Bailer empty. RIH w/3.84" GR and 3.70" centralizer to 703' KB. Worked tools couple times and could not get past this depth. POOH. RIH w/2-1/2" x 5' DD bailer to 7,671' KB. Work tools to 7,673' KB.Set jars off twice to come free. POOH. Bailer had approx 2' of dry contaminated cement. RIH w/X line running tool and located X-nipple at 5,490' KB. X nipple was at 5,492'-5,494' on Pollard GPT log. POOH. PT tubing to 1,600 psi for 15 min.Test good. Pressure was solid. RIH w/2-1/2"x 5' DD bailer to 5,621' KB.Tool set down, pick back up and went right thru down to 7,671' KB. Plug did not move down hole during PT. POOH. Bailer had metal marks on bottom. Bailer had same kind of sample cement as last bailer run. Add additional 30' lubricator. RIH with 3-1/2" x 40' dump bailer(empty) as a drift run and set down at 7,673' KB.Jar down and came out of hole. Glass bottom had broke ok (needs to break to let cement out). POOH. Mix, load 17# Neo cement in bailer and RIH at 150 fpm and set down at 5,621' KB. Picked up and went right thru down to 7,673'. (Did not show any sign of dumping cement at 5,621' KB).Jar down and break glass bottom to unload cement (17 gals-27') on top of bad cement at 7,673' KB. Lost 50 to 75 lbs of tool weight when cement dumped. Worked bailer to insure all cement dumped. POOH. Glass was broke and everything looked good. Cement in Place at 23:00 hrs and est top of cement at 7,646' KB. Rig down lubricator and turn well over to field. 07/19/2015-Sunday 4' • Meet at office and mobe to location. PTW and JSA. Rig up lubricator. PT lubricator to 250 psi low and 2,000 psi high. RIH w/2- 1/2" x 5' bailer and tag at 7,651' KB (Est TOC at 7,648' KB). Hit down twice and go to 7,673' KB. Spud with bailer 2 times and go to 7,675' KB. POOH. Had same powder cement in bailer. 7,673' KB is where we were when we dump bailed 27' of cement. Call town and talk over. RIH with 3.82" GR and braided line brush and set down at 703' KB. Pick up and go a little faster and went right thru to 1,200' KB. Set down and did the same as before and went right down to 5,540' KB (Liner hanger ZXP packer and PBR. Pick up and find X Nipple at 5,493'. Must be washed out because GR shouldn't have gone thru it(3.813" ID).You could tell by wt indicator when we went thru it. POOH. Swab well from 0'to 1,250' KB with no problems. Depth pretty much matched the fluid we were getting back in tank. Ran 2-1/2" bailer down to 7,676' and tag cement. Did this to make sure plug hadn't moved while bailing. Cont to bail from 1,250' KB to 4,000' KB. POOH. RIH w/3.75 GR and tag cement at 7,678' KB to check and see if plug moved. POOH. NOTE: Strapped 65.52 bbls fluid out of tank. 4,100' = 62.32 bbls fluid. Rig for standby. Will be back in AM to finish swabbing. 07/20/2015- Monday Meet at office and mobe to location. PTW and JSA. Rig up lubricator. PT lubricator to 250 psi low and 2,000 psi high. Swab well from 4,091 'to 5,620' with no problems but couldn't swab any deeper. We tried small bites and bigger bites but would lose fluid going thru hanger, packer, PBR and XZ nipple 5,400'to 5,540' and then thru GLM (5,007') and chem inject mandral at 2,099'. Could not get fluid to surface.Also found kink in line at 2,500'. Switch over to .125 wire. RIH w/2-1/2" x 20' bailer (to get fluid sample and check obstruction depth) and tag fill at 7,614' KB. Obstruction moved up hole 64' according to this tag. POOH, got same type cement out bailer. RIH w/X line running tool and located X-nipple at 5,510' KB. X nipple was at 5,492'-5,494' on Pollard GPT log. Adjusted depth and this put TOC/plug approx 7,596' KB instead of 7,678' KB where we got tag yesterday. Looks like cement/plug moved after swabbing off 1,650' more of fluid. Rig down lubricator and turn well over to field.Tank had some solids in it before we started so the strap is going to be off some. It strapped out as 89.18 bbls swabbed (5,859') and if you go by depth where FL ended up which is 5,620'.That equals 85.42 bbls. So it is real close to strap and depth. Left fluid samples at office to experiment with cement. 08/14/2015- Friday PTW and ISA.Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. RIH w/2.75" CIBP, tie into Pollard Plug Log#1 and tag fill at 7,541'. Set plug at 7,540'. Lost 150 lbs tool weight when plug set. Picked up 30' and went back down and tagged plug. POOH. 0 psi on tubing when plug was set. Rig down lubricator and turn well back to field. 08/18/2015-Tuesday Meet at office. Mobe to location. PTW and ISA. Spot equipment and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high. RIH w/2-7/8" x 20' PJ HC, 6 spf, 60 degree phase perf gun and tie into Pollard GPT log dated 7-10-15. Run correlation log and send to town. Get ok to perf the LB-5B sand from 7,495'to 7,515'.Tubing pressure is 52 psi. Fired gun and pressure went to 75 psi in 5 min. RIH w/2-7/8" x 14' PJ HC, 6 spf, 60 degree phase perf gun and tie into Pollard GPT log dated 7-10-15. Run correlation log and send to town. Get ok to perf the LB-4D sand from 7,376' to 7,390'.Tubing pressure is 90 psi. Fired gun and pressure went to 125 psi in 5 min. RIH w/2-7/8" x 20' PJ HC, 6 spf, 60 degree phase perf gun and tie into Pollard GPT log dated 7-10-15. Run correlation log and send to town. Get ok to perf the LB-4B sand from 7,293'to 7,313'. Tubing pressure is 800 psi. Fired gun and pressure went 850 psi and to 900 psi in 5 min. Out of hole and tubing pressure is 975 psi. Rig down lubricator and turn well over to field. • Kenai Gas Field n • Well: KTU 32-07 SCHEMATIC Last Completed: 1/04/2001 llileorp Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' 3:; 7' Intermediate 23/L-80/N/A 6.366 Surface 5,040' 13 3/s" 29/P-110/N/A 6.184 5,040' 5,690' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' z. TUBING DETAIL 9-soI \ , 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' k i 1 Max Inclination JEWELRY DETAIL 28.74°@ 2,771' .% No Depth ID Item .,.° I 2 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel 2 5,007' 3.833 4-1/2"GL Mandrel 3 3 5,400' 3.875 Baker S-3 Packer above tied into liner top w/o seals 4 5,499' 3.813 Otis X nipple 5 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR y i4 6 7,540' N/A CIBP 7 7,596' N/A CIBP Capped with 25'Cement Y - $t, 8 9,050' N/A HES Gun Hangar ti ' '. 9 9,074' N/A HES 10K EZ Drill s V. 4 :4 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Date Status LB-4B 7,293' 7,313' 6,825' 6,845' 20 6 08/18/2015 Open 7" , LB-4D 7,376' 7,390' 6,908' 6,922' 14 6 08/18/2015 Open LB-5B 7,495' 7,515' 7,027' 7,047' 20 6 08/18/2015 Open T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 01/09/2001 Partially Covered T 73-1 7,703' 7,710' 7,234' 7,241' 7' 6 01/09/2001 Covered T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 01/09/2001 Covered T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 01/09/2001 Covered T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 09/29/2000 Covered T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 09/13/2000 Covered LB-0s CEMENTING DETAIL LB-4D Casing Detail _ 9-5/8" 12-1/4"hole w/400sks of cement a ''- u2,_513u2,_5137" 8-1/2"hole w/445sks of cement •,� •• 6 4-1/2" 6-1/8"hole w/675sks of cement 7 TOF @ 8,191'3/4/14 dry puddy bells cf sand ? M Fish:@9,027 *BakerHyd.OscorreU ' Prop Frac'd perfs w/21,6941bm of *Circulating Valve *Nawdnl 1 Motor % carbonate using gelled diesel-11/14/2000 *4 Bladed Junk Nall *I-ES 10K FAS Dill *Composite Plug II'll II'll 8 4-1/2" ...m �' 9 TD=9,117'/PBTD=9,047' Updated by DMA 09-18-15 immwomminsimmonmsemomimminsmoimminsm - OF � � w*I////,' THE STATE Alaska Oil and Gas '1 of K /` Conservation Commission Witt_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFrrn ALAS1� Fax: 907.276 7542 5atalE© JUL 0 y U 015 ¢'� R www aogcc.alaska.gov Stan Porhola �/ v a Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool, KTU 32-07 Sundry Number: 315-406 Dear Mr. Porhola: 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, ia-7 74^ Cathy P Foerster Chair DATED this36 "day of June, 2015 Encl. RLC; . 'iti:, • STATE OF ALASKA G /36/!S ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 6 tiu i J APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO CIA Cr . 1.Type of Request: Abandon❑ Plug Perforations Q • Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate 0• Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool E Repair Well ❑ Re-enter Susp Well ❑ Other. Coil N2 2 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: Number 5.Permit to Drill Exploratory ❑ Development ❑ • 200-023 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El6.API Number. Anchorage,Alaska 99503 50-133-20491-00 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 510a - Kenai Tyonek Unit(KTU)32-07 Will planned perforations require a spacing exception? Yes ❑ No Q - 9.Property Designation(Lease Number): 10.Field/Pool(s): A-028142 ' Kenai Gas Field-Beluga/Upper Tyonek 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): 9,117 • 8,648• 6,467 6,014 N/A 8,191'(Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 123' 13-3/8" 123' 123' Surface 1,510' 9-5/8" 1,510' 1,509' 5,750 psi 3,090 psi Intermediate 5,690' 7" 5,690' 5,294' 6,340 psi 3,830 psi • Production Liner 3,573' 4-1/2" 9,117' 8,648' 8,430 psi 7,500 psi 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 5,540' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): S-3&ZXP Packer and N/A 5,400'(MD)/5,036'(TVD)&5,540'(MD)/5,160'(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 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: 7/10/2015 OIL ❑ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 2WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email soorholad3lhilcorD.com Printed Name Stan Porhola Title Operations Engineer • Signature / G*i'..._ Phone 907-777-8412 Date 6/2.O/-- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Ll(J Subsequent Form Required: /0 —416 V APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: _3(J-/S' 1'1 OcIl8PIlMoA Submd Form and Form 10-403Lsei5 Ed for 12 months from the date of air. chments in Duplicate RBDM _V - 1 2U15 Ab 4, 34)./S- • Well Prognosis Well: KTU 32-07 llilcorp Alaska,LL' Date: 6/26/2015 Well Name: KTU 32-07 API Number: 50-133-20491-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: July 10th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-023 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 1,319 psi @ 6,426' TVD (Based on fluid level in 2014 cleanout) Maximum Expected BHP: 1,319 psi @ 6,426' TVD (Based on fluid level in 2014 cleanout) Max. Allowable Surface Pressure: —676 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Kenai Tyonek Unit 32-07 (KTU 32-07) is a Tyonek producer drilled in 2000 with the perforated interval ranging from the Tyonek 72-8 sand at 7652' MD to the Tyonek 86-2 sand at 9042' MD. Since the beginning of production this interval has had problems staying above the critical velocity to keep the well unloaded. Water production began at small rates (<1BWPD) initially but increased to 10 BWPD within the first two years of production. The completion is a 4.5" monobore with a chemical injection mandrel at 2099' and a gas lift mandrel at 5007'. The well was able to produce above the unloading rate briefly in 2003 but was unable to maintain this rate likely due to sand and water production increasing with time. A SBHP measured on 7/7/2010 showed the formation has 1320 psi and should be able to sustain production but the well cannot flow above the unloading rate. On 9/08/2013 operators attempted to flow the well because the SITP was 340 psi but this was a gas cap above the fill and the well died in 10 minutes likely because of the sand covering the perfs. Sand production has filled the tubing to above the top perf with the last tag at 6467' SLM on 9/22/2013 indicating all perforations are covered by fill. The well was cleaned out to 8,191' CTM in March 2014 using coil tubing. A planned velocity string in 2014 was never installed. The purpose of this work/sundry is to add perforations in the Lower Beluga. Notes Regarding Wellbore Condition S 11.30 • Well is currently producing 55 mcf/d @ 65 psi FTP. Slickline Procedure: 1. MIRU Slickline, PT Lubricator to 1,500 psi Hi 250 Low. 2. RU 3.75" gauge ring, RIH and tag fill at+/-8,191'. 3. RIH and set bridge plug at 7,640'. 4. Dump bail 25' of cement on top of bridge plug (16.0 gallons of cement). 5. Wait on cement for 24 hours. 6. RU 3.0" bailer and tag top of cement. a. Dump additional cement if cement top is below 7,615'. 7. Fill well with lease water. Pressure test plug to 1,500 psi for 30 min. 8. RD Slickline. Coiled Tubing Procedure: Well Prognosis Well: KTU 32-07 Ililcorp Alaska,LL Date: 6/26/2015 9. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 10. RIH w/ 1.75" coil to 7,615' MD and tag top of cement. 11. Displace well fluids with Nitrogen. a. Estimated volume of displaced produced water is 116 bbl. 12. Leave well with 750 psi Nitrogen SITP. 13. POOH w/coil. 14. RD Coiled Tubing. E-line Procedure: 15. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. a. Tree connection is 6.5" OTIS. b. SITP will be 750 psi (Nitrogen Pressure). 16. RU 2-7/8" 6 spf Connex HC wireline guns. 17. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Lower Beluga LB-4B 7,293' 7,313' 20' 6 Lower Beluga LB-4D 7,376' 7,390' 14' 6 Lower Beluga LB-5B 7,495' 7,515' 20' 6 a. Bleed tubing pressure to 750 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using CBL Log dated 9/08/00 (Bond Log Tie-in log). d. Use Gamma/CCL/to correlate. e. Record tubing pressures before and after each perforating run. f. Proposed intervals are in the Beluga/Upper Tyonek Gas Pool. g. Spacing allowance is based CO 510a; no wells within 1,500' of property border. 18. RD E-line. 19. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil BOPE Schematic Kenai Gas Field Well: KTU 32-07 . n SCHEMATIC Last Completed: 1/04/2001 Hilcorp Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' ::,.:: 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' 7" Intermediate 23/L-80/N/A 6.366 Surface 5,040' 13-3/8" 29/P-110/N/A 6.184 5,040' 5,690' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' 9-5�8" I €' , TUBING DETAIL 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' 1 Max Inclination • +' i. JEWELRY DETAIL 28.74°@ 2,771' No Depth ID Item D ' 2 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel 2 5,007' 3.833 4-1/2"GL Mandrel 4 E4 3 3 5,400' 3.875 Baker S-3 Packer above tied into liner top w/o seals . 4 5,499' 3.813 Otis X nipple 5 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR 4 6 9,050' N/A HES Gun Hangar • 7 9,074' N/A HES 10K EZ Drill ?�► PERFORATION DETAIL s i , Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status y Y r T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 1/9/2001 Covered T 73-1 7,703' 7,710' 7,234' 7,241' 7' 6 1/9/2001 Covered Tik s T 73-1 7,840' 7,854' 7,371' 7,385' . 14' 6 1/9/2001 Covered p, lik , T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 1/9/2001 Covered >' T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 _ 9/29/2000 Covered . T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 9/13/2000 Covered i. CEMENTING DETAIL Casing Detail • 9-5/8" 12-1/4"hole w/400sks of cement 1' 7" 8-1/2"hole w/445sks of cement ,Z. 4-1/2" 6-1/8"hole w/675sks of cement I 'g. I i • i 1 TOF@8,191'3r4/14dry --ie paddy balls of sand Fish:@9,027 *BakerHyd.Discerrr>ed ; Prop Frac'd perfs w/21,6941bm of *Circulating Valve carbonite using gelled diesel-11/14/2000 *NaodnI Mach 1 Motor *4 Bladed Junk MII . - *HES 10K FAS Dill *Cmposite Plug • 101 _11 -: 6 4-112" TD=9,117/PBTD=9,047 Updated by DMA 03-13-15 Kenai Gas Field 14 Well: KTU 32-07 PROPOSED SCHEMATIC Last Completed: 1/04/2001 nileorp Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21'5 Size Type Wt/Grade/Conn ID Top Btm !! 13-3/8" Conductor 61/K-55/N/A 12.515 Surface 123' i 9 5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' 7" Intermediate 23/L-80/N/A 6.366 _ Surface 5,040' 13-3/8". 29/P-110/N/A 6.184 5,040' 5,690' 1y 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' ^t TUBING DETAIL 9-5/5" ! ft 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' 1 Max Inclinationirj JEWELRY DETAIL 28.74°@ 2,771' is'° No Depth ID Item t 2 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel 2 5,007' 3.833 4-1/2"GL Mandrel , (411 3 3 5,400' 3.875 Baker S-3 Packer above tied into liner top w/o seals 4 5,499' 3.813 _ Otis X nipple ,,, S 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR ';, 4 6 9,050' N/A HES Gun Hangar 9 7 9,074' N/A HES 10K EZ Drill PERFORATION DETAIL ' 5 Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Date Status ' ,,r LB-4B 7,293' 7,313' 6,825' 6,845' 20 6 Proposed g ` �: LB-4D 7,376' 7,390' 6,908' 6,922' , 14 6 Proposed , .wj LB-5B 7,495' 7,515' 7,027' 7,047' 20 6 Proposed o• V T72-8 7,652' 7,682' 7,183' 7,213' 30' 6 1/9/2001 Partially T' 4 'k Covered T 73-1 7,703' 7,710' 7,234' 7,241' 7' 6 1/9/2001 Covered T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 1/9/2001 Covered T 75-8 7,966' 7,980' 7,497' 7,511' _ 14' 6 1/9/2001 Covered c,gp T 84-6 _ 8,888' 8,916' 8,419' 8,447' 28' 6 9/29/2000 Covered T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 9/13/2000 Covered /° i.30-/f CEMENTING DETAIL Casing Detail LB-413 9-5/8" 12-1/4"hole w/400sks of cement Clef'@7,640 I - 7" 8-1/2"hole w/445sks of cement Capped va/25'Cmt - LB'4D :4, , : ,-' ,tit, 4-1/2" 6-1/8"hole w/675sks of cement LB-5B TCF @8 191 3!4!14 dry paddy balls of sand Fish:Cd29,022' TakerHyd.Disconnect •a Prop Frac'd perfs w/21,6941bm of "Circulating Valve =4 `Navidril Mach 1 Mot« - carbonite using gelled diesel-11/14/2000 "4 Bladed Junk MII \ ' `HES 10K FAS Drill * *Canposite Plug , 7,...„.,- ,k. + ._ k6 4-1/2" i 7 1D=9,117/PBTD=9,047 Downhole Proposed Updated by STP 06-26-15 Kenai Gas Field „ft KTU 32-07 IIil.-rrrl. v,,.t„1.L IU. 6/26/2015 Kenai Tyonek Unit 32-07 133/8X95/8x7a41/2 Coil Tubing BOP Lubricator to injection head .�.rl�r 1.75"Tandem Stripper I 1 0•1 .I,I Blind/Shea.= 1/161. =.BIind/Shear liii.fl ii .Ill.Blind/Shear - _Ma Blind/Shear.I,'•_ • j II��Mai 1=1 M I1'lI Olorari RCM- III■I•i i Mud Cross e ti6N=It- ;� 4 1/16 10M0;11/16 lOM 1141**�1N'� O �I� O iso toil w/2-201/16 10M full opening FMC valves Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 111 2 1/16 10M 2 1/16 10M Crossover spool 4 1/16 10M X 4 1/16 5M O' 4a\ skl‘ Se‘ Valve,Swab, t • , _tsF y OVG-230,4 1/16 5M FE,HWO, • r- -4 ,a4�1., 6, DD trim •' J .,,'ti pis �i• p.oQ Tee,stdd,4 1/16 SM X I �s 3 1/8 5M ff IN� ire: Valve,upper master, ii-• 4 ••rl VG-230,4 1/16 SM FE,HWO, DD trim Willy ifm"iii■ iiii, Valve,master, ..c �� z• VG-230,4 1/16 SM FE,HWO, DD trim IP • 11 U U II STATE OF ALASKA • A. ,KA OIL AND GAS CONSERVATION COM, SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon L] Repair Well L Plug Perforations L] Perforate L] Other L] CTU CO Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory ❑ 200-023 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20491-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028142 Kenai Tyonek Unit 32-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai/Up Tyonek Beluga Gas 11.Present Well Condition Summary: Total Depth measured 9,117 feet Plugs measured N/A fee,R E C E I V E D true vertical 8,648 feet Junk measured 8,191 (fill) feet MAR 1 6 2015 Effective Depth measured 6,467 feet Packer measured 5,400&5,540 feet true vertical 6,014 feet true vertical 5,036&5,160 feet AOGCC Casing Length Size MD ND Burst Collapse Structural Conductor 123' 13-3/8" 123' 123' 3,090 psi 1,540 psi Surface 1,510' 9-5/8" 1,510' 1,509' 5,750 psi 3,090 psi Intermediate 5,040' 7" 5,040' 4,717' 6,340 psi 3,830 psi Intermediate 650' 7" 5,690' 5,294' 11,220 psi 8,530 psi Liner 3,573' 4-1/2" 9,117' 8,548' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic pppw�y��'( SCANNED ;,:';_a., G' Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 5,540'MD 5,150 ND Packers and SSSV(type,measured and true vertical depth) S-3&ZXP Pkr;N/A 5,40015,540'MD 5,036'/5,160'ND 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 40 223 Subsequent to operation: 0 282 5 40 60 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ 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: —244-1311- 31 4- 10I Contact Chad Helgeson Email chelaesont�hilcorp.com Printed Name 01#811/: Chhad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date 3_\(s,—t3_I RBDMS MAR 1 7 2015 Form 10-404 Revised 10/2012 7 /�"" ,/Z34.5.------ Submit Original Only RECEIVED Hilcorp Alaska, LLC Post Office Box 244027 MAR 1 6 2015 Anchorage,AK 99524-4027 AOGCC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Phone: 907/777-8405 March 16, 2015 Fax: 907/777-8510 Guy Schwartz Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: KTU 32-07 AOGCC Sundry #314-109 API # 50-133-20491-00 (PTD 200-023) Dear Mr. Schwartz: Enclosed is the completed AOGCC 10-404 Report of Well Operations for Sundry 314- 109. Hilcorp originally requested permission for a coil tubing unit clean out and velocity string install; however, only the coil clean out was completed. A velocity string was not , necessary and not installed. Sincerely, HILCORP ALASKA, LLC 1/04/ Chad Helgeson Operations Manager :dma Enclosures cc: File Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date KTU 32-7 50-133-20491-00 200-023 3/3/14 3/4/14 Daily Operations: 3/3/2014- Monday Hold PJSM. Discuss JSA and emergency procedures. Obtain SPW and Hot work for Steam on Wheels. Start equipment. Circulate MEOH across tree. Prepare for BOP Test. Visually function test BOP's. Close Blind rams and choke. Test blinds and choke to 250psi low/4,500psi high. Test good. Insert 1-3/4" test bar. Close pipe rams. Test pipes, inside reel valve, and N2 check valve. Test 250psi low/4,500psi high. Test good. Test accumulator. BOP test complete. PU injecator and BHA. BHA is 1-3/4" dimple on, DFCV, circ sub, hydraulic disconnect, 3' straight bar, and 2" forward jet nozzle. Open valves to choke. Open swab valve. RIH pumping KCL at min rate. Clean-out from 6,590'to 8,000'. OOH. Close swab valve. ND Injector. Install night cap. Secure well and location for the night. 3/4/2014-Tuesday Hold PJSM. Discuss JSA. Obtain SWP and Hot Work for Steam on Wheels. Start equipment and crane. Mix 3 loads of KCL water. ND night cap. PU injector. NU on WH. Open swab valve. SITP 843psi. RIH w/ 1-3/4" BHA and forward jet nozzle. Start pumping KCL .5 BPM. Start pumping N2 at 500 scf/min. Clean-out from 8,000'to 8,191'. OOH. All surface lines plugged with dry puddy balls of sand. Last couple hundred feet appeared to have brought up 3-4 bbls of puddy like sand which plugged up the WH and flow lines. Cleared the flowline and WH by circulating N2 and .75 BPM KCI with a closed swab valve. Then we RIH pumping .75 BPM KCL and 750 scf/m N2 down thru the WH. RIH to 370'. Cut KCL and blew well dry w/ N2. ND injector. Installed night cap. Secured well. Lined valves to flow to the FB tank and turned the well over to production. Kenai Gas Field rWell: KTU 32-07 SCHEMATIC Last Completed: 1/04/2001 Hilcorp Alaska,Lu: API: 50-133-20491-00 CASING DETAIL RKB=87/AGL=21' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Structural 61/K-55/N/A 12.515 Surface 123' 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' 7" Intermediate 23/L-80/N/A 6.366 Surface 5,040' iso/s' 29/P-110/N/A 6.184 5,040' 5,690' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' TUBING DETAIL 9-5/8" ! , i 4-1/2" Tubing 1 12.6/L-80/N/A 3.958 Surface 5,540' 1 Max Inclination 1 1r 5 JEWELRY DETAIL 28.74°@ 2,771' -•,;' 0 , No Depth ID Item 41 2 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel i•o. 2 5,007' 3.833 4-1/2"GL Mandrel ' ." 3 3 5,400' 3.875 Baker S-3 Packer above tied into liner top w/o seals 4 5,499' _ 3.813 Otis X nipple 5 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR %'4 6 9,050' N/A HES Gun Hangar }• 7 9,074' N/A HES 10K EZ Drill ,i :i PERFORATION DETAIL 5 1-' " Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status r" ‘1.$�1.t Partially T72-8 7,652' 7,682' 7,183' 7,213' 30' 6 1/9/2001 Covered r.4. T73-1 7,703' 7,710' 7,234' 7,241' 7' 6 1/9/2001 Covered , s s'h t T 73-1 7,840' _ 7,854' 7,371' 7,385' 14' 6 1/9/2001 Covered 1.T'S. :, -, T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 . 1/9/2001 Covered ,,-.1 T 84-6 8,888' _ 8,916' 8,419' 8,447' 28' 6 9/29/2000 Covered T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 9/13/2000 Covered ', CEMENTING DETAIL ". 4, Casing Detail r, 9-5/8" 12-1/4"hole w/400sks of cement • 7" 8-1/2"hole w/445sks of cement 1 A 4-1/2" 6-1/8"hole w/675sks of cement r I ;A. A t), t 1a w; f TOF @8,191'3x4/14 dry paddy balls d sand a• T'4 Fish:09,022 -1' "BakerFlyd.Disconnect ". +s.'`` Prop Frac'd perfs w/21,6941bm of *Circulating Valle r ".0 carbonite using gelled diesel-11/14/2000 "Navidril Mach 1 Motor ,, . rE,C 1. "4 Bladed Junk MII '.,", 1-ES 10K FAS Drill 7 '•= 'Composite Plug ", .3 • ( I ljI -, 6 4-1/2" * a TD=9,117/PBTD=9,047 Updated by DMA 03-13-15 ee,,\\I%%� k'. 1 HE STATE A. a. ` ' _ e,}-,'-], , c. . _ 333 West Seventh Avenue GOVERNOR SEAN AIt \1 L% Anchorage Alaska 9950' 3572 Z Main 907 279 /33 � �� F �a�Er o).. 7U/.2/6./;4) schtee AUG Q 6 2014; Paul Chan Operations Engineer Hilcorp Alaska, LLC d0 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Kenai Field, Upper Tyonek Beluga Gas Pool, Kenai Tyonek Unit 32-07 Sundry Number: 314-109 Dear Mr. Chan: 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, , 7)L4e_Aj/-r/'---- Cathy P. oerster Chair DATED this Zi day of February, 2014. Encl. R tr STATE OF ALASKA FEB 2 4 2014$ ALASKA OIL AND GAS CONSERVATION COMMISSION 01--J 2-4 z71 I Cf-- APPLICATION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ ,l- c. Time E�tension Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install Velocity String 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q• 200-023 3.Address: Stratigraphic ❑ Service 1:16.API Number. 3800 Centerpoint Drive,Anchorage AK,99503 50-133-20491-00-00 . 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 Kenai Tyonek Unit 32-07 • 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028142 • Kenai Field/Up Tyonek Beluga Gas . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,117 . 8,648 6,467 • 6,014 • N/A 6,467'(Fill) Casing Length Size MD TVD Burst Collapse Structural 123' 13-3/8" 123' 123' 3,090psi 1,540psi Surface 1,510' 9-5/8" 1,510' 1,509' 5,750psi 3,090psi Intermediate 5,040' 7" 5,040' 4,717' 6,340psi 3,830psi Intermediate 650' 7" 5,690' 5,294' 11,220psi 8,530psi Production Liner 3,573' 4-1/2" 9,117' 8,648' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic. See Attached Schematic 4-1/2" 12.6#/L-80 5,540' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): S-3&ZXP Packer and N/A 5,400'(MD)/5,036'(TVD)&5,540'(MD)/5,160'(TVD)and N/A 12.Attachments: Description Summary of Proposal Q . 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: 3/4/2014 Oil ❑ Gas 2' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is - and correct to the best of my knowledge. Contact Paul Chan Email pchanc hilcorp.com Printed Na e Paul A Title Operations Engineer Signature Or Phone 777-8333 Date 2/24/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: G, \�_ ids Plug Integrity ❑ BOP Test [�' Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,k Li Soft p 5,, 3oP si-- RBDW14. MAY 1 0 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0— 411 WI APPROVED BY Approved by: , ! _77v€44,___ COMMISSIONER THE COMMISSION Date: , __(27_/g Z Z(''1`l i ei A Pmt atl �� Subs Form and Form 10-403(Rev d 10/2012) ApprOv'p� 1 e/K� Onths from the date o a proval. Attachments in Duplicate . Well Prognosis Well: KTU 32-07 Hilcorp Alaska,LLC Date:2/24/2014 Well Name: KTU 32-07 API Number: 50-133-20491-00 Current Status: Shut In Leg: N/A Estimated Start Date: March 4th, 2014 Rig: N/A Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398(0) Permit to Drill Number: 200-023 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)345-3161(H) (907)444-2881(C) Second Call Engineer: Mike Dunn (907)777-8382 (0) AFE Number: Current Bottom Hole Pressure: —1319 psi @ 6426' TVD based on fluid level Maximum Expected BHP: —1319 psi @ 6426' TVD based on fluid level Max.Allowable Surface Pressure: —1126 psi (Based on actual reservoir conditions and gas gradient to surface 0.03 psi/ft) Brief Well Summary KTU 32-07 is a Tyonek producer drilled in 2000 with the perforated interval ranging from the Tyonek 72-8 sand at 7652' MD to the Tyonek 86-2 sand at 9042' MD. Since the beginning of production this interval has had problems staying above the critical velocity to keep the well unloaded. Water production began at small rates (<1BWPD) initially but increased to 10 BWPD within the first two years of production. The completion is a 4.5" monobore with a chemical injection mandrel at 2099'and a gas lift mandrel at 5007'. The well was able to produce above the unloading rate briefly in 2003 but was unable to maintain this rate likely due to sand and water production increasing with time. A SBHP measured on 7/7/2010 showed the formation has 1320 psi and should be able to sustain production but the well cannot flow above the unloading rate. On 9/08/2013 operators attempted to flow the well because the SITP was 340 psi but this was a gas cap above the fill and the well died in 10 minutes likely because of the sand covering the perfs. Sand production has filled the tubing to above the top perf with the last tag at 6467'SLM on 9/22/2013 indicating all perforations are covered by fill. Notes Regarding Wellbore Condition 1. Min ID—Halliburton 4-1/2"X nipple @ 5499' MD w/3.813" min ID 2. Max Angle—28.74 deg @ 2771' MD 3. Last Tag—2.5" Bailer @ 6467'SLM on 09/22/2013 OBJECTIVE OF WORKOVER Perform CT FCO to TOF at 9,022' MD with N2 and 6%KCI brine. Run 2-3/8" CT deployed velocity string to "7622' MD. Pre-CT Procedure: 1. Close lower master valve. Bleed off pressure and check for flow. 2. Remove upper master valve. Install new Vetco 41/16 5M shoulder type coiled tubing head w/2 1/16 5M side outlet. Install wing section on coil head. 3. Reinstall upper tree assembly. Well Prognosis Well: KTU 32-07 Hilcurp Alaska,LLC Date:2/24/2014 4. Test new tree assembly to 500si for 15 minutes. 5. Have production come in and get measurement to build/modify flow lines and S-risers. CT FCO and V-string Procedure: 6. MIRU Coiled Tubing Unit and tanks as needed. 7. NU BOP stack on tree and function test BOP's 8. Test BOP stack, swab valves and choke manifold per AOGCC(250 psi low/4500 psi high test). Notify AOGCC 24 hrs in advance of BOPE test at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 9. Stab pipe into injector head and install FCO BHA with jetted nozzle. Install injector on BOP stack and secure. 10. Line out pump to flow cross ensuring all valve alignment is correct for BOP test. 11. Fill coil and perform Shell Test on all treatment lines and equipment with 6% KCI brine (500 psi low test r and 4500 psi high test). 12. Cleanout well to 9022' MD with N2, 6% KCI brine, and foamer as needed. Note fish at 9022' MD. Take f returns to flowback tank and add defoamer as needed. If, 13. Once the well is cleaned out to TOF, blow well dry with N2 and POOH. 14. Prepare to run 2-3/8" CT velocity string. / 15. PU into lubricator and secure the well. 16. Raise injector head up enough to cut off coil connector. yv(o . 17. MU new coil connector with straight bar, PXN nipple and aluminum pump-off plug. Pull test connector. 5--4'‘') 18. Stab back on to BOPE. 19. RIH with 2-3/8"velocity string to^'7622' MD. 20. Set CT in BOPE pipe/slip rams. Mechanically lock in rams. Blow down pressure. 21. Raise injector head up enough to cut and dress coil for hanger,. Swing injector head away. 22. M/U Vetco coil tubing hanger with GS profile to 2-3/8" CT. 23. MU GS tool assembly to coil on reel with 2-3/8" coil connector. Pull test connector. 24. Latch GS spear to Vetco mandrel's GS profile. Remove any safety clamps on the coil if used. Bring injector back down to BOP. Pull test coil mandrel connection and GS spear assembly to 5K over string weight. Equalize stack. Unlock rams and open BOP. 25. Land out hanger in coil head. Tighten lockpins. Pressure test between the seals on the test port to 5000psi. 26. Release the 3"GS running tool and pull up into the lubricator. 27. Pressure upthe 2-3/8" CT velocitystringwith N2 and blow out the aluminum pumpout plug. p g 28. RD CT unit and all support equipment. 29. Turn well over to operations. Attachments: 1. Current and Proposed Wellbore Schematic 2. Proposed wellhead and tree schematic 3. CT BOPE Schematic - Kenai Gas Field Well: KTU 32-07 SCHEMATIC Last Completed: 1/04/2001 Metal)Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21' Size Type Wt/Grade/Conn ID Top Btm `` ‹ 13-3/8" Structural 61/K-55/N/A 12.515 Surface 123' E 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' 7" Intermediate 23/L-80/N/A 6.366 Surface 5,040' 1.3-30 '; 29/P-110/N/A 6.184 5,040' 5,690' ( �4 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,117' '1 TUBING DETAIL 45/g / 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' kTr 1 Max Inclination y JEWELRY DETAIL 28.74"@ 2,771' j No Depth ID Item !b 2 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel 2 5,007' 3.833 4-1/2"GL Mandrel s ,, ;, , 3 3 5,400' 3.875 Baker S-3 Packer above tied into liner top w/o seals ' 4 5,499' 3.813 Otis X nipple >f'' 5 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR A 4 6 9,050' N/A HES Gun Hangar 7 9,074' N/A HES 10K EZ Drill 4 sr r PERFORATION DETAIL , • 5 •y Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) FT SPF Date Status 1 • 't T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 1/9/2001 CovePartireld d . T 73-1 7,703' 7,710' 7,234' 7,241' 7' 6 1/9/2001 Covered {`h` ► T73-1 7,840' 7,854' 7,371' 7,385' 14' 6 1/9/2001 Covered s T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 1/9/2001 Covered 4 T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 9/29/2000 Covered •: Kenai Gas Field . ilEol Well: KTU 32-07 PROPOSED Last Completed: 1/04/2001 Hulcor')Alaska,LLC API: 50-133-20491-00 CASING DETAIL RKB=87'/AGL=21' Size Type Wt/Grade/Conn ID Top Btm 0 13-3/8" Structural 61/K-55/N/A 12.515 Surface 123' 2' ' 9-5/8" Surface 40/L-80/N/A 8.835 Surface 1,510' V, rik 7" Intermediate 23/L-80/N/A 6.366 Surface 5,040' 13-3/8" 29/P-110/N/A 6.184 5,040' 5,690' r 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 5,540' 9,113' } ' .1 TUBING DETAIL 9-s/s" - 4-1/2" Tubing 12.6/L-80/N/A 3.958 Surface 5,540' "n ,. 1 2-3/8" V-String .188 Wall/QT-800 1.99 Surface ±7,622' Max Inclination 28.74'@ 2,771' JEWELRY DETAIL 2 No Depth ID Item 4S' 1 2,099' 3.833 4-1/2"Chemical Injection Mandrel flc _<' 3 2 5,007' 3.833 4-1/2"GL Mandrel t- 3 5,400' 3.875 Baker S-3 Packer above tied into liner top w/o seals i'rlit„ 4 5,499' 3.813 Otis X nipple 4 5 5,540' N/A Baker Flex Lok Liner Hangar w/ZXP Pkr and PBR 6 9,050' N/A HES Gun Hangar f,;2 ,c17 9,074' N/A HES 10K EZ Drill 1 PERFORATION DETAIL ra,1 m ,,,,, $ , Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Date Status rsa t T 72-8 7,652' 7,682' 7,183' 7,213' 30' 6 1/9/2001 Partially Covered �� T73-1 7,703' 7,710' 7,234' 7,241' 7' 6 1/9/2001 Covered T' T 73-1 7,840' 7,854' 7,371' 7,385' 14' 6 1/9/2001 Covered 3,, T 75-8 7,966' 7,980' 7,497' 7,511' 14' 6 1/9/2001 Covered T 84-6 8,888' 8,916' 8,419' 8,447' 28' 6 9/29/2000 Covered e T 86-2 9,028' 9,042' 8,559' 8,573' 14' 6 9/13/2000 Covered •* CEMENTING DETAIL 7.0Z .t Casing Detail 9-5/8" 12-1/4"hole Cmt w/400 sks IV .1 :,. ,1 Z ,: x Fish:09.027 "Baker Ftyd.Q Prop Frac'd perfs w/21,694lbm of 'Circulating Valve Navid-il Mach 1 Moto- s carbonite using gelled diesel-11/14/2000 '4 Bladed Junk Kill "FES 10(FAS Drill - .; 'Composite Plug - *v' ... ..It, 6 41/2" i • ,. A 7 TD.9,117'/PBTD=9,047 Revised By:TDF 2-20-2014 Kenai Gas Field KTU 32-07 Proposed Coil 02/23/2014 flikwp Alaska.1.1.0 Kenai Gas Field Tubing hanger,MB-150,11 X KTU 32-07 4.909 MCA lift X4%:IBT susp, 133/8X95/8X7X41/2 w/4"Type HBPV profile,2- ''/continuous control lines 6.5"Extended neck Coiled tubing hanger,VG- CTM,4"nominal X 2 3/8 EUE susp X 3"GS Baker Fish Neck Lift,w/2"Type H BPV and grapple for 2 3/8"coil Tree cap,Otis,4 1/16 5M FE X 6'/:Otis Quick Union x © 1 uuesu_e®iui \ ` � •s C.,C,' ae �� OO Valve,Swab, 11 n �`< Jai 3ti es` VG-230,4 1/16 5M FE,HWO, Ja ti\, .. �N.' V. DD trim 0, O 44i.A�\ �° L3 O 4\ °�llaud J() --- -7 Tee,stdd,41/165M X \ /1 . `. i, ,„.•^Al.T c 3 1/8 5M :10.. it, �© vv.:,,- se ...-er ,..e.: , 41.. 14 IPA' Valve,upper master, VG 230,4 1/16 SM FE,HWO, V u.ft DD trim _(J0 V 1a 1k °, '�, 2 1/16 5M Wing section Coiled Tubing head,Vetco w/Pneumatic SSV Gray,4 1/16 5M FE X a �' A i-) 4 1/16 5M stdd,w/1- I f' . 21/165MS50, U ..s : �� Load shoulder type head i r %1>°6) �'r,i � /11 Valve,master, �<��jyV (dw� Y VG-230,4 1/16 5M FE,HWO, s DD trim 41 ",„„1916..a r. Adapter,Vetco,11 5M stdd X 40' ll U 4 1/16 5M stdd top,prepped f/6.5"extended neck hanger Multibowl,Vetco MB-150, •. 113M stdd bottom X \;,;Z 11 5M FE top,w/ �" 2-2 1/16 5M SSO,1-control line exit ra '°' =11 01. 4 c I fe.*: ' el Starting head, 'I I Vetco MB-150, ' 11 3M X 9 5/8 SOW bottom, _it L= w/2-2"LPO ni I I _1 1113 3/8" 9 5/8" 7" 4.5" Kenai Unit KTU 32-7 Hilnnr:%laoka.l.11; Baker BOP Stack Infected'Connactor-� Two Door Strippcv Packer 111:113 Mt. all immins amiumg c-a Lthrtvar Hyidracarrn Svrgsrr tly�dracoon \ ■rte Sid$wir7der&row ppm' r anal- •ate animo 011111110 1551111 ES Series tluad NOP—,,, . . . . .1111 _..-111 14:14— :1 ■a1 t—_ 1 I- r Fcw Cross LS Serres Uva'Card& ' I. IIIA : .11rMl _ H AL~SBA OIL AI~TD GAS CO1~T5ERQATIOAT COM~'IISSIOl~ Ken D. Walsh Senior Production Engineer Marathon Oil Company ~~~ JUL ~ ~ 2008 PO Box 1949 Kenai, AK 99611-1949 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~ ~3 Re: Kenai Gas Field, Upper 7~onek/Beluga Gas Pool, Kenai ~onek Unit 32-7 Sundry Number: 308-257 Dear Mr. Walsh: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely ft it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Se~.tnount, Jr. Chair DATED this? day of July, 2008 Encl. • M Marathon MARATHON Oil Company July 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Kenai Gas Field Well: Kenai Tyonek Unit 32-7 Dear Mr. Maunder: • .Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 y ~ql~~:~~-~ ~~~ ~~ ~ j ~ ~G~Qg ~~~'~• ~; ,~;~ ~ M Enclosed is the 10-403 Application for Sundry Approvals requesting permission to clean out solids from the KTU 32-7 wellbore. Fill was recently tagged in KTU 32-7 at 7,674' MD. This indicates that 80% of the perforated intervals are covered over with fill, leaving only 22' of open perforations. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~~~~ Kevin Skiba Engineering Technician Enclosures: 10-403 App. For Sundry Approvals cc: AOGCC Operations Program Houston Well File Current Well Schematic Kenai Well File KJS KDW ~~~ STATE OF ALASKA ~=2-K-~~ ALA OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 i.~r,~rt ~ ~~~~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate- ~S Waiver ^ Other ^~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Coil Tubing Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Clean Out 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: ' Development ^, Exploratory ^ 200-023 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20491-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: S i E i R ^~ ^ Kenai Tyonek Unit 32-7 - pac ng xcept on equired? Yes No 9. Property Designation: - 10. KB Elevation (ft): 11. Field/Pool(s): F~',D A - 028142 ~ 8T (21' AGL) ' Kenai Gas Field /Tyonek Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,117' ` 8,648', 9074' 8605' 9074' 9022' Casing Length Size MD TVD Burst Collapse Structural 102' 13-3/8" 123' 123' 3,090 psi 1,540 psi Conductor Surface 1,488' 9-5/8" 1,510' 1,509' 5,750 psi 3,090 psi Intermediate 5,273' 7" 5,690' 5,294' 7,240 psi 5,410 psi Production Liner 3,573' 4-1/2" 9,113' 8,644' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,652' - 9,042' 7,183' - 8,573' 4-1/2" L-80 5,540' Packers and SSSV Type: Packers and SSSV MD (ft): ZXP Liner Top Packer 5,400' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 23, 2008 Oil ^ Gas Q Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative; 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Senior Production Engineer Signature Phone Date ~ (907) 283-1311 July 17 2008 ' ~ , ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integri st ^ Location Clearance ^ ~`° ~"`a ~ ~,~~y Y `` ` Other: 1..,'~`C~Q ~~` ~~ ~.`7'"~'. ~~ `0.'l ~ - Q ~~! ~.. ~ ~ Zoos . Subsequent Form Required: ~ , °, ; .', ~'a ~ ~it~~ 2 910D8 -;' APPROVED BY / ~ ~ ~ ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: ~~ n Form 10-403 Revised 06/2006 ORIGINAL Submit in Duplicate • • M MARATHON MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KTU 32-7 Coil Tubing Cleanout Procedure (7-15-2008) WBS # Requested ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Notes: cc.~ ~~c-~c~ ~ ~ c~~ F-~lacvc~~ C;~ • This procedure covers work to clean out 4-1/2" casing using 1.75" OD coil tubing. • Top of fish is at 9022' MD and bottom of Tyonek 84-6 perf is at 8916' MD. °~1~~ • Slick line tag 7/11/2008 indicated fill to 7674' KB. Objective: Clean out well using CTU to a minimum and maximum depth of 9000' MD. Return well to production. Procedure• 1. MIRU MOC flow-back eauipment. Including open-top flow-back tank, choke skid, gas buster, and flow back iron. MIRU 500 bbls. Rain-for-Rent fluid supply tank. ASRC to lay liner and berm area around tanks and wellhead. Fill supply tank with 6%KCL w/ 1 gal/m FRW-14. Deliver ASRC 40T crane, diesel fuel man-lift, and two light towers. Electricians to LOTO electrical connections. Then remove well house. 2. MIRU BJ 13/4" coil tubing and nitrogen. Conduct pre job safety meeting and obtain Safe Work Permit. Spot CTU with 13/4" CT work reel, and pumping equipment. Nipple up on WH w/ 4-1/16" 5 M flange and flow cross. RU 2" hard line from flow cross to choke skid, and then to Gas Buster. Test CT BOP's to 250/4500 psi with 6% KCL water. Document BOP test and submit necessary report to AOGCC. Test flow-back iron 250/4500 psi with 6%KCL water. Stab CT work string in injector. Make up CT dimple-on connector. Pull test connector to 15 K. *** Notify the AOGCC James Regg C7 907-276-7542 (24 or longer) prior to testing the BOP's 3. Make up tool string with 2" Swirl Jet Nozzle. Carry injector to well head. Pressure test Bowen connections to 1500 psi. Open well and RIH w/ CT pumping 6% KCL water at minimum rate. At 7600' increase pump rate to 1-1 /2 bpm. If returns are less than 1 for 1 consider using N2. Clean out well to 9000' MD. Reciprocate and wash perforations as necessary. Pump bottoms up twice or until returns come back clean. KTU 32-7 Coil Tubing Clean Out Procedure MBS - 7/16/2008 9:42:47 AM Page 2 of 2 • • 4. Jet in well. Reduce KCL pumping rate to .25 bpm and bring on N2 @ 700- 750 scf/m. POOH jetting well dry. 5. RD infector and lubricator. RDMO BJ coiled tubing and nitrogen units. Release rental equipment and ensure that all liner, drums, etc have been disposed of properly. Haul off water from returns tank to G&I. RD flow-back iron. Release tanks and all rental equipment to vendors. 6. Place well on sales. Prepare and submit Form 10-404 sundry report to the AOGCC for this work history. Consider reperforating some or all of the intervals if production results are considerably less than expected (no funding including for reperfs in the WBS request). CONTACTS Ken Walsh: 907-283-1311 (w) 907-394-3060 (cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 Emergency Dial 911 David Martens: 713-296-3302 (w) 832-472-6249(cell) Dennis Donovan: 907-283-1333 (w) 907-398-1362 (cell) KTU 32-7 Coil Tubing Clean Out Procedure MBS - 7/16/2008 9:42:47 AM Kenai Tyonek Unit 32-7 qpl'#'~~ 50-133-20491-00-00 Pad 41-7 Prop. Des: A- 028142 37' FNL, 4,268' FEL, Sec. 7, KB elevation: 87' (21' AGL) T4N, R11 W, S.M. Latitude: MARATHON Longitude: 4-1/2" Chemical Injection Mandrel •_ @ 2099' wlo a profile (3.833" Drift ID) 4-112" GL Mandrel @ 5007' •- (3.833" Drift ID) ~ Baker S-3 Pkr @5400' MD above tied into liner top w/o seals (3.875" ID) ~~ Otis X nipple @ 5499' MD (Min ID 3.813" ID) r Baker Flex Lok Liner Hanger w/ ZXP Pkr and PBR top ~ 5540' MD Max Inc 27.39 degrees ish: @ 9,022' MD 'Baker Hyd disconnect 'Circulating valve 'Navidril Mach 1 Motor '4 bladed junk mill 'HES 10K FAS Drill "Composite plug Middle Beluga ~ Fill @ 7,674' MD 8/6/2000 8/26/2000 ~'~ v' Structural Pioe 13-3/8" K-55 81 ppf Top Bottom MD Surf 123' ND Surf 123' Surface Casino 9-5/8" L-80 40 ppf Top Bottom MD 0' 1,510' ND 0' 1,509' 12-114" hole Cmt w/ 400 sks Intermed iate Casing 7" L-80 23 ppf Top Bottom MD 0' 5,040' ND 0' 4,717' P-110 29 ppf MD 5,040' 5,690' ND 4,717' 5,294' 8-1/2" hole Cmt w/ Liner 4-1/2" L-80 12.6 ppf Hydril 521 Top Bottom MD 5,540' 9,113' ND 5,160' 8,644' 8-118" hole Cmt wl Tubing 4-1/2" L-80 12.6 ppf Top Bottom MD 0' 5,540' ND o' s,1so' 73-1 U Perfs 7,703-7,710' 73-1 mid Perfs 7,840-7,854' 8: 7,878-7,880' 75-8 Perfs 7,966-7,980' All 6 SPF 60 deg (01-09-01) Prop frac'd perfs w/21,694 Ibm of carbolite using gelled diesel (11-14-00) Tyonek 84-6 Perfs 8,888-8,916' 6 SPF STIMGUN (09-29-00) '~s-~'q C~a~.'"'I~ ~ , ~ j,~ Tyonek 88-2 Perfs from 9,028-9,042' 6 SPF (09-13-00) .: ~A r ~ f HES gun hanger 1111 HES 10K EZ Drill @ 9,074' MD Estimated Formation Toos MD ND 9,050' MD Sterling 3,838' 3,652' TD PBTD Upper Beluga Middle Beluga 4,988' 5,750' 4,670' 5,347' 9,117' MD 9,074' MD Lower Beluga 6,524' 6,362' 8,648' ND 8,605' ND Tyonek 7,633' 7,164' Well Name & Number: Kenai Tyonek Unit 32-7 lease: Kenai Gas Field County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations (MD): 7,652' - 9,042' Perf (ND): 7,652' - 9,042' Angle @KOP and Depth: Angle @Perfs: KOP ND: Date Completed: January 18, 2001 RKB: 21' Prepared By: Kevin Skiba Last Revision Date: July 17, 2008 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ,~ ~\, MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the D 1 sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU 2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177 -029 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-1 79 KBU 44-06 SCA[~N[ËfC) JA~~ 2 ~ 2004 I Permit to Drill 2000230 DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. KENAI TYONEK UNIT 32-07 Operator MARATHON OIL CO APl No. $0-133-20491-00-00 MD 9117 -'""~" TVD 8648 ~'~ Completion Dat 1/18/2001 ~"-' Completion Statu 1-GAS .Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log Nc) Sample No Directional Survey N_.~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) L L L L L L L L L L L L Interval Log Log Run OH I Dataset Name S.c~Ie Media ~ Start Stop CH Received Number PEX-DT/NT/GPJCAL4'''~ 2/5 ~ 1510 5680 OH 8/22/2000 DTINTIGPJCAL-TVDC"'~/5 i~t 1510 5282 OH 8/2212000 PEX'DT/NL/GR4"'~/5t_ ~.. (~ 5690 9090 OH 9/2212000 PEX-AIT/MCFL/G~2/5 ~, 5690 9090 OH 9/22/2000 MUD-TV 1500 8650 OH 9/22/2000 U U D-M D ~,,,,-"~' /~2~ 1500 9121 OH 9~22~2000 R Final Well Report / FINAL CH 1/5/2001 L GPJCCL/Perf,_~" 8600 9020 1/9/21~01 L Slim Sonic DT ~ 4200 9073 1/9/2001 L Slim Sonic CBL/VDL 5400 9073 1/9/2001 L GPJCCL/Perf ~ 8730 9073 1/9/2001 5380 9070 Case 2/21/2001 C 9889 ~ FINAL CH 2/21/2001 · - o. L PEX-AIT/GPJCAL 2/5 1510 5680 OH 8/22/2000 Comments 1510-5680 1510-5282 BL(C) 5690-9090 BL(C) 5690-9090 EPOCH 1500-8650 8/9/00 THRU EPOCH 1500-9121 8/9/00 THRU Final Well Report 8600-9020 Print 4200-9073 Print 5400-9073 Print 8730.-9073 Print 09889 ~80-9070 9889 "~ Sonic Digital Data 1510-5680 4484-5208 1510-5282 1510-5680 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments I Cuttings 5700 9121 Permit to Drill 2000230 MD 9117 TVD Core Chips DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. KENAI TYONEK UNIT 32-07 Operator MARATHON OIL CO 8648 Completion Dat 1/18/2001 Completion Statu 1-GAS Current Status 1 -GAS APl No. 50-133-20491-00-00 UIC N ................. ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis '-~ ~ N Re. ce. ived? Daily History Received? ~) / N Formation Tops (~1 N Comments: Compliance Reviewed By: Date: Alask!, ,~.,gion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 12, 2001 Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 1000 Anchorage, AK 99501 Reference: KTU 32-7 Dear Mr. Maunder: Attached is a FORM 410-407 WELL COMPLETION OR RECOMPLETION REPORT AND OG. If you have any questions or need additional information, I can be reached at 564-6303 or riaffinito~marathonoil.com. Sincerely, Ralph Affinito Production Engineer A subsidiary of USX Corporation Environmentally aware for the long run. " STATE OF ALASKA ~i' A .,KAOILAND GAS CONSERVATION CO ..SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL~---1 GAS~'~ SUSPENDED~] ABANDONED~'] SERVICE[~1 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 200-023 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20491-00 Classification of Service Well 4. Location of Well at Surface ,, 37'FNL, 4268'FWL, Sec. 7, T4N, R11W, S.M. At top of Producing Interval ... ~...;_... 2050'FNL, 3402'FWL, Sec. 7, T4N, R11W, S.M. ! -d-~/-b:~."-~-L At Total Depth 2050'FNL, 3402'FWL, Sec. 7, T4N, R1 lW, S.M. · KB A-028142 12. Date Spudded 113. Date T.D. Reached 8/6/2000 I 8/26/2000 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 9117' MD, 8648' 'I'VD 9010' MD, 8541' TVD 22. Type Electric or Other Logs Run AlT, Neutron/Density, cased hole sonic 9. Unit or Lease Name Kenai Unit 10. Well Number KTU 32-7 11. Field and Pool Kenai Gas Field 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1/1812001 I N/A feet MSL I one 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost Yes~'~No ~I N/A feet MD I N/A 23 CASING SIZE WT. PER FT. GRADE CASING, LINER AND CEMENTING RECORD SE ~ ~NG DEPTH MD TOP BOTTOM 13-3/8" 61 K-55 0 100' 9-5/8" 40 L-80 0 1510' HOLE SIZE CEMENTING RECORD AMOUNT PULLED Driven Driven N/A 12-114" 400 sks N/A 7" OD 23-29 L-80 0 5690' 8 112" 445 sks N/A 4-1/2 12.6 L-80 5540' 9113' 6-1/8" 675 sks N/A 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD Tyonek 72-8 7652-7682 6 SPF (01-12-01) 8562-8573 Tyonek 73-1U 7703-7710 6 SPF (01-12-01) 7234-7241 Tyonek 73-1L 7840-7854 6 SPF (01-09-01) 7371-7385 SIZE I DEPTH SET (MD) 4 1/2" 12.6# I 5540' I PACKER SET (MD) 5400' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 27. Tyonek 73-1L 7870-7880 6 SPF (01-09-01) Tyonek 75-8 7966-7980 6 SPF (01-09-01) Tyonek 84-6 8888-8916' 6 SPF (09-29-00) Tyonek 86-2 9028-9042' 6 SPF (09-13-00) Date First Production 18-Jan-01 Date of Test Hours Tested 1/23/2001 24 Flow Tubing Pres. Casing Pressure 1710 N/A 28. 7401-7411 7497-7511 8562-8573 8419-8447 DEPTH INTERVAL (MD) Tyonek 84-6 8888-8916' PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) flowing IPRODUCTION FOR OIL-BBL IGAS-MCF TEST PERIOD ~ 0 I 1432 CALCULATED OIL-BBL IGAS-MCF 24-HOUR RATE ~. 0 I 1432 IAMOUNT & KIND OF MATERIAL USED 21694 Ibm carbolite w/487 bbls gelled diesel WATER-BBL 0 WATER-BBL 0 I CHOKE SIZE IGAS-OIL 20/64 I N/A OIL GRAVITY-APl (corr) N/A RATIO Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded gas bearing sandstone, shale and coal. RECEIVED MAR I 3 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 N:\drlg\kgf~wells\Ktu32-7~AOGCOMPL.xls CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Sterling Gas 3755' 3669' Interbedded sandstone, silt shale and thin coals Beluga 4985' 4784' Interbedded sandstone, silt shale and thin coals Tyonek 7628' 7271' Interbedded sandstone, silt, shale, and coal 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that t.he foregoing is true and correct to the best of my knowledge Signed ~~ Ralph Affinito Title Production Engineer Date 3/12/2001 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECEIVED Form 10-407 N:\drlg~kgfwells~ktu32-71AOGCOMPL.xls Alaska Oil & Gas Cons. Commission Anchorage Marathon Oil Compm{' Survey Report .' Company: Marathon. Oil Company · · · Field: - Kenai Gas Field. · Site: . · Pad 41-7 · - · . Well: ' KTU'32-7 . . Weilpath: OH Original hole " · Date:' .02/26/2001 " .... 'Time:' 12:52:57 . Page: .' '... 1" ...' Co-ordinate(NE)Reference: .. Well: KTU 32-7, True North : ... . Vertieal.(TVD)..Reference: ..... SITE:87,0 ... .. . . ..... .: ..:.'.." Section (VS) Reference: ·.Well (0.00N,0.00E,201.90Azi) . ' Survey Calculation Method: ' Minimum Curvature Db: '. Sybase ... Field: Kenai Gas Field Kenai, Alaska usa Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: Wmm_95 Site: Pad 41-7 Section 7 Centered on KU 13-5 Site Position: From: Map Position Uncertainty: 0.00 ff Ground Level: 0.00 ff Northing: 2361844.31 ft Latitude: 60 27 32.631 N Easting: 275073.22 ft Longitude: 151 14 45.826 W North Reference: True Grid Convergence: -1.08 deg Well: KTU 32-7 Slot Name: Well Position: +NbS 128.79 ft Northing: 2361971.88 ft Latitude: 60 27 33.899 N +E/-W 63.17 ft Easting: 275138.82 ft Longitude: 151 14 44.566 W Position Uncertainty: 0.00 ft Weilpath: OH Original hole Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: SITE Height 87.00 ff Above System Datum: Mean Sea Level Magnetic Data: 00/00/2000 Declination: 21.51 deg Field Strength: 0 nT Mag Dip Angle: 0.00 deg Vertical Section: Depth From (TVD) +N/-S +E]-W Direction ff ff ff deg 0.00 0.00 0.00 201.90 Survey: Survey #1 Start Date: 08/07~2000 Company: Marathon Oil Company Engineer: Marathon Oil Company Tool: MWD/GYRO, Tied-to: From Surface Survey: Survey #1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD/GYRO 166.00 0.62 18.50 166.00 0.85 0.28 -0.g0 0.37 0.37 0.00 MWD/GYRO 344.00 0.88 359.90 343.98 3.13 0.59 -3.13 0.20 0.15 -10.45 MWD/GYRO 430.00 0.97 318.40 429.97 4.~ 0.10 -4.06 0.~ 0.10 -48.26 MWD/GYRO 540.00 1.58 270.60 539.95 5.05 -2.03 -3.93 1.07 0.55 -43.45 MWD/GYRO 646.00 2.46 250.90 645.88 4.32 -5.64 -1.90 1.05 0.83 -18.58 MWD/GYRO 737.00 3.87 241.80 736.74 2.23 -10.19 1.73 1.64 1.55 -10.00 MWD/GYRO 825.00 4.04 241.40 824.53 -0.66 -15.53 6.40 0.20 0.19 -0.45 MWD/GYRO 917.00 2.90 242.50 916.36 -3.28 -20.44 10.67 1.24 -1.24 1.20 MWD/GYRO 1013.00 2.55 245.70 1012.25 -5.28 -24.54 14.06 0.40 -0.36 3.33 MWD/GYRO 1138.00 1.32 266.40 1137.18 -6.52 -28.51 16.68 1.12 -0.98 16.56 MWD/GYRO 1322.00 0.88 334.30 1321.15 -5.38 -31.24 16.64 0.70 -0.24 36.90 MWD/GYRO 1452.00 1.05 332.50 1451.13 -3.42 -32.23 15.20 0.13 0.13 -1.38 MWD/GYRO 1528.00 1.10 333.20 1527.12 -2.15 -32.88 14.26 0.07 0.07 0.92 MWD/GYRO 1580.00 1.10 258.70 1579.11 - 1.81 -33.59 14.20 2.56 0.00 -143.27 MWD/GYRO 1630.00 3.69 215.40 1629.07 -3.21 -34.99 16.03 5.97 5.18 -86.60 MWD/GYRO 1735.00 5.63 209.40 1733.72 -10.45 -39.48 24.42 1.90 1.85 -5.71 MWD/GYRO 1835.00 7.65 204.90 1833.04 -20.77 -44.69 35.94 2.08 2.02 -4.50 MWD/GYRO 1898.00 9.05 202.10 1895.37 -29.16 -48.32 45.08 2.31 2.22 -4.44 MWD/GYRO 1980.00 11.07 200.00 1976.11 -42.53 -53.44 59.40 2.50 2.46 -2.56 MWD/GYRO 2065.00 13.45 198.20 2059.16 -59.60 -59.32 77.42 2.84 2.80 -2.12 MWD/GYRO 2145.00 15.20 199.30 2136.67 -78.33 -65.69 97.18 2.21 2.19 1.37 MWD/GYRO 2302.00 19.07 197.50 2286.68 -122.24 -80.21 143.33 2.49 2.46 -1.15 MWD/GYRO 2385.00 21.20 199.60 2364.60 -149.31 -89.33 171.85 2.71 2.57 2.53 MWD/GYRO Marathon Oil Compaq" · Survey Report .c°mP~my: .Marathon. Oil Company' meld: Kenai Gas. Field · Site:. Pad 41-7 ........ "W~II:' ..... "KTu 32-7 .. Wellpath: i OH Original hole Date: .. 02/26/2001. ...' Time:' 12:52:57 . .. Page: ' 2' Co~ordinate(NE)'Reference: Well: KTU 32-7,:True North ' .,: ' Vertical (TVD) Reference: SITE 87.0 .... ': .... . '... '. :s~¢ti~n"(VS)'Ref~mnce: ' .Wel! (0.00N:,O.00Ei201.9OAzi)'" ' Sm-vey CslcUlati°n MethOd: Minimum Curvature Db: ,' Sybase .. Survey: Survey #1 ." MD Inci' . Azim ' TVD +NFS .+E/-W ..... . VS DLS' ' ' '. Build Turn ' ' - Tool/Commeiit ' ' ' ' ft"" ="(leg · ~ 'deg '.' ' .'.ft'..' ' 'ft' ' ff.'.."... ' 'ft' ' ,' deg/i00ffdeg/100ft'deg/100ft". .... ..=" , ~=.'~'.= · ' .:" '. 2464.00 23.38 200.00 2437.69 -177.50 -99.48 201.80 2.77 2.76 0.51 MWD/GYRO 2525.00 24.43 199.60 2493.46 -200.76 -107.85 226.50 1.74 1.72 -0.66 MWD/GYRO 2648.00 27.69 199.60 2603.94 -251.65 -125.97 280.48 2.65 2.65 0.00 MWD/GYRO 2771.00 28.74 198.90 2712.32 -306.56 -145.14 338.57 0.90 0.85 -0.57 MWD/GYRO 2894.00 28.56 198.60 2820.26 -362.40 -164.10 397.45 0.19 -0.15 -0.24 MWD/GYRO 3017.00 28.39 197.80 2928.38 -418.11 -182.41 455.97 0.34 -0.14 -0.65 MWD/GYRO 3138.00 28.30 197.50 3034.88 -472.85 -199.83 513.26 0.14 -0.07 -0.25 MWD/GYRO 3262.00 28.13 197.50 3144.14 -528.76 -217.46 571.72 0.14 -0.14 0.00 MWD/GYRO 3385.00 28.56 199.25 3252.40 -584.18 -235.87 630.00 0.76 0.35 1.42 MWD/GYRO 3692.00 27.77 198.20 3523.05 -721.40 -282.41 774.68 0.30 -0.26 -0.34 MWD/GYRO 3803.00 26.89 198.90 3621.66 -769.72 -298.62 825.55 0.84 -0.79 0.63 MWD/GYRO 3999.00 26.72 200.00 3796.60 -853.06 -328.04 913.85 0.27 -0.09 0.56 MWD/GYRO 4122.00 27.86 201.40 3905.90 -905.80 -347.99 970.23 1.06 0.93 1.14 MWD/GYRO 4367.00 28.65 202.10 4121.71 -1013.52 -390.97 1086.21 0.35 0.32 0.29 MWD/GYRO 4495.00 28.13 201.70 4234.32 -1069.99 -413.68 1147.07 0.43 -0.41 -0.31 MWD/GYRO 4557.00 28.10 202.40 4289.00 -1097.07 -424.64 1176.29 0.53 -0.05 1.13 MWD/GYRO 4680.00 27.86 202.40 4397.62 -1150.42 -446.63 1233.99 0.20 -0.20 0.00 MWD/GYRO 4742.00 27.95 201.40 4452.42 -1177.34 -457.46 1263.01 0.77 0.15 -1.61 MWD/GYRO 4939.00 27.16 202.80 4627.07 -1261.78 -491.73 1354.13 0.52 -0.40 0.71 MWD/GYRO 5112.00 27.77 203.80 4780,57 -1335.05 -523.29 1433.89 0.44 0.35 0.58 MWD/GYRO 5251.00 27.07 204.20 4903.95 -1393.53 -549.32 1497.86 0.52 -0.50 0.29 MWD/GYRO 5332.00 28.21 204.70 4975.71 -1427.74 -564.88 1535.40 1.44 1.41 0.62 MWD/GYRO 5420.00 27.77 202.80 5053.42 . -1465.53 -581.52 1576.67 1.13 -0.50 -2.16 MWD/GYRO 5652.00 26.72 203.50 5259.68 -1563.19 -623.26 1682.85 0.47 -0.45 0.30 MWD/GYRO 5721.00 26.28 204.20 5321.43 -1591.35 -635.71 1713.62 0.78 -0.64 1.01 MWD/GYRO 5800.00 25.58 203.80 5392.47 -1622.91 -649.76 1748.14 0.91 -0.89 -0.51 MWD/GYRO 5935.00 23.73 202.40 5515.16 -1674.69 -671.87 1804.44 1.44 -1.37 -1.04 MWD/GYRO 6058.00 21.80 202.80 5628.58 -1718.63 -690.16 1852.03 1.57 -1.57 0.33 MWD/GYRO 6131.00 21.36 204.20 5696.46 -1743.25 -700.86 1878.87 0.93 -0.60 1.92 MWD/GYRO 6232.00 20.39 202.10 5790.83 -1776.33 -715.02 1914.84 1.21 -0.96 -2.08 MWD/GYRO 6331.00 18.90 201.10 5884.06 -1807.27 -727.28 1948.12 1.54 -1.51 -1.01 MWD/GYRO 6434.00 15.64 202.80 5982.41 -1835.65 -738.67 1978.69 3.20 -3.17 1.65 MWD/GYRO 6498.00 14.85 201.70 6044.16 -1851.22 -745.04 1995.52 1.31 -1.23 -1.72 MWD/GYRO 6591.00 15.21 202.40 6133.97 -1873.57 -754.10 2019.64 0.43 0.39 0.75 MWD/GYRO 6684.00 11.78 201.70 6224.39 -1893.68 -762.26 2041.34 3.69 -3.69 -0.75 MWD/GYRO 6783.00 11.87 201.40 6321.29 -1912.55 -769.71 2061.62 0.11 0.09 -0.30 MWD/GYRO 6868.00 11.16 200.00 6404.58 -1928.41 -775.72 2078.59 0.90 -0.84 -1.65 MWD/GYRO 6969.00 9.93 200.00 6503.87 -1945.78 -782.04 2097.06 1.22 -1.22 0.00 MWD/GYRO 7089.00 8.88 198.50 6622.26 -1964.29 -788.52 2116.65 0.90 -0.87 - 1.25 MWD/GYRO 7174.00 7.56 199.60 6706.38 -1975.78 -792.47 2128.78 1.56 -1.55 1.29 MWD/GYRO 7274.00 5.38 203.50 6805.74 -1986.28 -796.55 2140.04 2.22 -2.18 3.90 MWD/GYRO 7407.00 2.37 201.00 6938.42 -1994.56 -800.02 2149.03 2.27 -2.26 - 1.88 MWD/GYRO 7510.00 0.09 296.30 7041.39 -1996.52 -800.86 2151.15 2.31 -2.21 92.52 MWD/GYRO 7694.00 0.35 146.90 7225.39 -1996.92 -800.68 2151.46 0.23 0.14 -81.20 MWD/GYRO 7816.00 0.35 184.50 7347.39 -1997.61 -800.51 2152.03 0.18 0.00 30.82 MWD/GYRO 7945.00 0.35 166.90 7476.39 -1998.38 -800.45 2152.73 0.08 0.00 -13.64 MWD/GYRO 8039.00 0.44 189.80 7570.38 -1999.02 -800.44 2153.32 0.19 0.10 24.36 MWD/GYRO 8191.00 0.97 190.10 7722.37 -2000.86 -800.77 2155.15 0.35 0.35 0.20 MWD/GYRO 8271.00 0.97 196.10 7802.36 -2002.18 -801.08 2156.48 0.13 0.00 7.50 MWD/GYRO 8440.00 0.70 220.00 7971.34 -2004.34 -802.14 2158.89 0.26 -0.16 14.14 MWD/GYRO 8563.00 0.97 221.10 8094.33 -2005.70 -803.30 2160.59 0.22 0.22 0.89 MWD/GYRO 8685.00 1.23 232.70 8216.31 -2007.27 -805.02 2162.69 0.28 0.21 9.51 MWD/GYRO 8807.00 1.23 227.30 8338.28 -2008.96 -807.03 2164.99 0.09 0.00 -4.43 MWD/GYRO Marathon Oil Compm(' Survey Report i. Company: Marathon Oil Company Field: Kenai Gas Field Site:....:. Pad. 41-7... . .': ':. Well: KTU 32-7 Wellpath: . OH'0riginal hole ' Datei "02/26/2001. - Tkae: = 12:52i57 .. ": ..... Page: .. ' '- .' Co-ordinate(N~)~ Reference: ' "Well: KTU 32-7~ True North. ..... :.. V~Cal.(T¥1))R~ecence; .. S!TE.87.0" '.. ' ....... · '" '. .' · ...'. Section. (VS) Reference: Well .(0.00N,0.00E,201..90Azi)..' · Survey Calculation Method: Minimum.Curvature Db: Sybase : Survey: Survey #1 ' ' MD ... Incl' "Azim . TVD +NAS · +E/-W ' VS" 'DLS'.. Build'' Turn::'': ':'i. TOOl/Comment.. "'] ':'.' .ff"! "" ' deg' · .. deg':. ":..:..' . ff.'... ' . · . . 'ff -~ff.... ..'"fi' '".. ~ -. deg/l'00ff. deg/100ff deg~100ff..... . .':.'.! ".'":; "i' "' ':: . ' '" / 8864.00 1.23 227.30 8395.27 -2009.79 -807.93 2166,10 0,00 0.00 0,00 MWD/GYRO RECEIVED Alaska Oil & Gas Cons, Commission Anchorage MARATHON OIL COMPANY ALASKA REGION APl: KB: GL: SURFACE LOC: BOT HOLE LOC: SPUD: COND CSG: SURFACE CSG: INTERMED. CSG: LINER: TD: KTU 32-7 Well History 50-133-20491-00 87 feet 65.4 feet 39' FNL 4232' FWL Sec 07, T4N, R11W, S. M. 2050' FNL 3402' FWL Sec 07, T4N, R11W, S. M. August 06, 2000 13-3/8" 61 ppf K-55 driven to 100 feet 9-5/8" 40 ppf L-80 to 1504' cemented w/400 sks 7" 23-29 ppf L-80 to 5690' cemented w/445 sks 4-1/2" 12.6 ppf, L-80 Hydril 521 from 5540-9113 cemented w/675 sks 9117' MD/8648' TVD Aug 06, 2000 Sep 07, 2000 Sep 08, 2000 Sep 11,2000 Sep 12, 2000 Sep 15,2000 04,200O RJAI:03PM 02~01 Spud Well. Drill w/12-1/4" bit to 1510'. Ran 9-5/8" 40 ppf L-80 csg to 1510'. Cemented csg w/400 sks. Drill out w/8-1/2" bit to 5700'. RU Schlumberger logging service and run PEX w/Density/Neutron/Induction/GR from 5680-1510' in addition to RFT log. Ran 7" 23-26 ppf L-80 BTC csg to 5690' MD. Cemented csg w/445 sks. MU new BHA of 6-1/8" bit and drill out shoe. Perform leak off test to 13.0 ppg EMW. Directionally drill to 8864' MD. RU core bbl and cut core from 8864-8895'. Resume drilling w/6-1/8" bit to 9117' MD TD. RU Schlumberger logging service and run OH logs as follows: Run #1 - PEX / AlT / Neut / Dens / CMR from 9117-5770 Run #2 - PEX / AlT / Neut/Dens / from 9117 to 5770' Run #3 - CMR / Neut - Unable to get down below 5760' Run #4 - DSI / NGT - Unable to get down below 5761'. Run 4-1/2" Hydril 521 12.6 ppf L-80 Liner w/Baker ZXP liner hanger and packer from 5540- 9113'. Cement liner in place with 675 sacks of Class G receiving full returns. Bump plug and observe float holding. Test liner top to 1000 psig. Make clean out run to 9075'. Run 4-1/2" 12.6 ppf IBT-M L-80 tubing w/Baker S-3 packer, GL mandrel, and chemical injection valve into string. Stab into liner, set packer, pressure test backside and hanger. Installed BPV and tested tree - all fine. Released Glacier Drilling Rig #1 on September 02, 2000. Remove BPV. RU Slickline and pull PX plug. Run GR to TD. RD Slickline unit. RU Schlumberger logging. Set Halliburton CIBP at 9072'. Run Accoustic Arrey / CBL log from 9072-4160'. RD WL unit. RU Slickline unit. Swab well down to 3650~ RD slickline unit. RU slickline unit. Run memory logging tool from 9072 - 8000'. RIH w/spacer and 2-3/4" perforating guns set to perforate the Tyonek 86-2 sand from 9028-9043' 6 SPF, 60 degree phased. Fired perforating guns and open well to gas buster. Retrieve guns and RD slickline unit. RU slickline unit. RIH w/gun hanger and 2-3/4" StimGun set to perforate the Tyonek 84-6 sand from 8888-8916' 6 SPF, 60 degree phased w/20' of propellent on center of gun. Fired perforating guns and open well to gas buster. Retrieve perf guns all shots fired. RD slickline unit. RU Slickline unit. Set orifice in GL valve at 5007' and unloaded well down to 5007'. Well would Nov 11,2000 Nov 14, 2000 Nov18,2000 Dec12,2000 Jan 04,2001 Jan 13,2001 Jan 18,2001 not flow. RU Schlumberger WL. Set Halliburton 10K FAS Drill plug at 9010'. RD WL unit. RU Dowell Fracturing equipment. Proppant fracture stimulate the 84-6 sand with 21,694 Ibm of ceramic proppant using 487 bbls of diesel. RD Dowell. Open well to zero flow. RU Dowell CT unit. Clean and jet well to plug at 9010' recovering 85 bbls of diesel. Well still did not flow. RU Slickline and find proppant fill covering 84-6 sand. RD slickline RU Schlumberger WL service. Blow well down from SITP of 4120 psig. Pressure test surface equipment to 4,500 psig. Perforate with 3.375" HSD guns loaded 6 SPF 60 degree phased with PJ 3406 HMX 22.7 gram charges. Sand Interval 72-8 7652-7882' 75-8 7968-7980' 73-1L 7870-7880' 73-1L 7840-7854' 73-1U 7703-7710' Total 75' RD Schlumberge WL service. Install flowline spool and turn well to sales with well bleading to zero in 30 minutes. Worked well over several days. Turn well to sales at 1,432 MCFGPD / 0 BWPD w/800 psig FTP. RJA 1:03 PM 02/26/01 ,~IARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 32-7 5-Aug-00 Continued rigging up Glacier Rig #1 on KTU 32-7. 6-Aug-00 Finished rigging up Glacier Rig #1. Spudded well at 0230 hrs. 8/6/00. Drilled from 22' to 155'. I 7-Aug-00 Drilled from 155' to 1510'. CBU. Made wiper trip to 155'. CBU. POOH to run casing. 8-Aug-00 Finished laying down BHA. R/U up casing tools. Ran and cemented 9 5/8" casing. Set @ 1,510'. WOC. Nippled down diverter. Cut off conductor and 9 5~8" casing. Welded on Braden head. 9-Aug-00 Finish weld on Braden Head. Test head 2000 PSI. Nipple up BOP's. Modify bell nipple, choke and kill lines. Test BOP's. 10-Aug-00 Finished testing BOP's. Picked up steerable BHA. Picked up to drill pipe and rack in derrick. Tripped in hole to top of cement @1419'. Tested casing 1500 psi. Drilled cement and floated equipment and 25' formation. Ran leakoff test to 18.4 lb/gal EMW. Directionally drilled F/1535'-2125'. 11-Aug-00 Directionally drilled with surveys F/2125'-4669'. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 32-7 12-Aug-00 Drilled from 4660' - 4725'. Made wiper trip to 3675'. Drilled to 5377'. POOH for Bit. 13-Aug-00 RIH. Drilled from 5377'-5700'. CBU. Made wiper trip to 4663'. CBU. POOH. Logged with Density/Neutron/GR/Induction Resistivity from 5680'-1510'. 14-Aug-00 Ran RFT. PJD loggers. LID MWD and motor. RIH. CBU. POOH. LID BHA. Installed and tested 7" casing rams. R/U to run casing. 15-Aug-00 Finished R/U to run casing. Ran and cemented 7" casing to 5690'. Tested BOPE. 16-Aug-00 Finished testing BOPE. Picked up new drilling assembly. RIH. Drilled cement and float equipment and 25' of formation. CBU. Performed leak off test. Drilled ahead from 5,725' to 5,867'. 17-Aug-00 Directionally drilled from 5,867'- 6,813'. 18-Aug-00 Drilled from 6,813' to 6,925'. Made wiper trip to 5,690'. Drilled to 7,300'. CBU. POOH for bit. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 32-7 19-Aug-00 Tripped for bit. Drilled from 7,300' to 7,649'. 20-Aug-00 Drilled from 7,649' to 8,100'. Made wiper trip to 7,383'. Drilled to 8,180'. 21-Aug-00 Drilled from 8,180'-8328'. CBU. Tripped from bit. Drilled to 8,336'. 22-Aug-00 Drilled from 8,336' to 8,733'.. 23-Aug-00 Drilled from 8,733 to 8,865'. CBU. Made wiper trip to 7,507'. CBU. Monitor well. POOH for coring assembly. 24-Aug-00 BHA. Tested BOPE. RIH with coring assembly. Cored from 8,865' to 8,895'. POOH. 25-Aug-00 POOH. BHA. L/D coring equipment. RIH. Reamed 30' to bottom. Drilled from 8,895'-9,004'. ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 32-7 26-Aug-00 Drilled from 9004' - 9117'. CBU. Wiper trip to 8505'. CBU. POOH for logging. 27-Aug-00 POOH. Logged. RIH for wiper trip. 28-Aug-00 RIH. CBU. POOH. Gas breaking out atbell nipple. RIH. 29-Aug-00 Circulate out gas. Raise mud weight to 12.0 ppg. POH. Lay down BHA. Rig up to run liner. RIH with production liner. Make up liner hanger and packer. Circulate liner volume. 30-Aug-00 RIH with liner on drill pipe. Liner stuck at 6508'. Worked liner free. Circulated and reduced mud weight to 11.5 ppg. Ran liner to 9113'. CBU. Cemented liner. Set packer and tested. CBU. POOH LID excess drill pipe. 31-Aug-00 LID drill pipe. Pick up cement mill and casing scrapers. Trip in hole and tag landing collar. Drill plug, landing collar, and cement to 9060'. Displace hole with 3% KCL water. 1-Sep-00 LID drill pipe. Installed and tested 4 1/2" rams. Ran 4 1/2" tubing and control line. ~VlARATHON OIL COMPANY ("' ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 32-7 2-Sep-00 TIH with tubing. Land tubing, set packer. ND BOPE, NU tree. Release rig. Prepare for demob. 3-Sep-O0 Demob. Started demob with reduced crews working daylight hours only. Changed pump liners, troubleshot PLC controls and performed rig maintenance. R/D topdrive and standpipe manifold. Load trailers. 4-Sep-00 Demob. R/D rig floor. Lowered derrick, substructure and degasser. Removed doghouses. Staged loads for the move. Loaded out mat boards. 5-Sep-00 Demob. Moved mat boards to new location and set in place. Finished RJD mudpit trailer and mud pump trailer. Rig is ready to move when road restrictions are lifted on September 5th. IKB=87 feet GL=66 feet IKTU 32-7 Tyonek Development Well 13-3/8" 61 Ibm/ft K-55 driven to 100' I 40 Ibm/It L-80 ~ ~1510' MD/TVD cmt~d in I 12-1/4" hole wi400 sks Estimated Formation Tops Sterling Upper Beluga Middle Beluga Lower Beluga Tyonek FD MD TVD 3838 3652 4988 4670 5750 5347 6524 6362 7633 7164 9117 8648 4-112" Chemical Injection Mandrel ~ 2099' w/o a profile (3.833" Drift ID) I 4-112" 12.6 Ibm/ft BTC L-80 from surface to 5540' MD I GL Mandrel ~ 5007' (3.833" Drift ID) Baker S-3 Pkr ~ 5400' MD above tied into liner top wlo seals (3.875" ID) Otis X nipple ~ 5499' MD (Min ID 3.813" ID) I Baker Flex Lok Liner Hanger w/Pkr and PBR top 1~ 5540' MD lax Inc 27.39 degrees 23-29 Ibm/ft L-80 ~ 5690' MD cm~d 8, 12" Hole 650' IS 29 PPF P-110 CSG 10K FAS Drill ~ 9010' MD IHES gun hanger ~ 9050' MD I HES 10K EZ Drill I~ 9074' MD I DOD 9075' MD TD = 9t17' ~ID :,,:. I Prop frac'd perfs w/21,694 ~b: of carbolite using gelled diesel (11-14-00) · '".':' ' 'i'.'' ":',', "'1 4-1/2 12.61bm/ttHydri1521 L-80 I I KTU 32-7 from liner top ~ 5540' MD to 9113'I I Kenai Gas Field Pad 41-7 MD cmfd in 6-118" Hole I , 6.5 Miles South of Kenai, Alaska 1/25/2001 ~°"~G~U~TOR~fflnltO ktu32-7 Alaskat' ,ion Dome~, roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 January 22,2001 Alaska Oil & Gas Conservation Commission Attn: Library - Lisa 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 LETTER OF TRANSMITTAL VIA AIRBORNE EXPRESS The following well data are enclosed: Marathon Oil Company KU 31-TX Final Mud Logging Report by Epoch, which includes Formation Log - 2"=100, MD & 2"=100' TVD and Drilling Dynamics Log - Paper Copies Caliper *Platform Express* - Paper Copy Density, Neutron, Sonic-Gamma Ray, Caliper - Paper Copy Dipole Sonic Imager - Paper Copy Repeat Formation Tester-Gamma Ray - Paper Copy Gamma Ray, Caliper *Platform Express* - Paper Copy Array Induction, Gamma, Ray, Caliper *Platform Express* - Paper Copy Density, Neutron, Sonic, Gamma Ray, Caliper - Paper Copy Open Sonic Data - CD Rom Marathon Oil Comnanv KU 32-7 Sonic Data - CD Rom Marathon Oil Company KU 14-32 I c~ oD -~) I ~ Completion Record 4.72" HSD, 12 SPF - Paper Copy & Reproducible Correlation Log - Paper Copy & Reproducible Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Exploration Aide Enclosures Airbill: 5333594921 Received by.~la~ (, 0a, ~..') A subsidiary of USX Corporation Environmentally aware for the long run. Alaskai" on Domest,,...roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 13, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 LETTER OF TRANSMITTAL VIA CERTIFIED MAIL The following well logs are enclosed: Print. O~h ~4~arath°n Oil Comoanv CLU-6 ~ - eRST-SIGMA- 1~)/1~/00 ............................................................................................................. 1 '/3-3/8" HSD Perforation - 10/23/00 ............................................................................................. 1 ~ClO"'O~ Marathon Oil Co~oanv KTU 32-7 vfCU 32-7 - 3.75 Gauge Ring/4.5 Plug, GR-CCL Perforating Record - 11/12/00 ................... 1 /KU 32-7 - SLIM Sonic Logging DT Combined Mode - 9/9/00 ................................................. 1 ,/KU 32-7 - SLIM Sonic Logging CBL-VDL - 9/9/00 ................................................................. 1 ~U 32-7 - Depth Determination, 4.5" Bridge Plug, GR-CCL, Perforating Record - 9/9/00 ...... 1 Marathon Oil Comoanv KBU 33-6Long /Cement Mappin~ Long, SCMT-PSP - 9/14/00 ............................................................................. 1 Marathon Oil Company SU 41-15 I/Completion Record, 2-1/8" Enerjets - 8/4/00 .......................................................................... 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Enclosures Certified Receipt No. 70000520002487427729 Received Date: 'lqlat A subsidiary of USX Corporation Environmentally aware for the long run. Alaska t 3n Domestk. ,-roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 October 31, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA AIRBORNE The following well data are enclosed: Marathon Oil Company CLU 6 Print/ Reoroducible :~ CLU 6 - SLIM Sonic Logging, Delta Compressional - 9/26/00 ................................................. 1 ........... 1 (film) .... CLU 6 Array Induction, MCFL Gamma Ray, Caliper, Platform Express - 9/18/00 ................ 1 ../.~ ....... 1 (film) */ CLU 6 - Density, Neutron Porosity, Gamma Ray, Caliper, Platform Express - 9/18/00 ............ 1 ..(.'. ...... 1 (film) '" CLU 6 Density, Neutron Porosity, Gamma Ray, Caliper, TVD - 9/18/00 ............................... 1 ...~..' ...... 1 (film) ~' CLU 6 Array Induction, MCFL, Gamma Ray, Caliper, TVD - 9/18/00 ................................... 1 ........... -- 1 (film) ''/ CLU 6 - Formation Log - TVD - 9/13-17/00 .............................................................................. 1 .f. ..... 1 (vellum) ,/ CLU 6 - Formation Log - MD - 9/13-17/00 ................................................................................ 1 ..Z.i ..... 1 (vellum) ,/ Marathon Oil Company KTI. J #32-7 - Final Well Report .............................................................. 1 "'" ! qq.o~.,{ Marathon Oil Company KBU #33-6 - Final Well Report .............................................................. 1 / Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Via Airborne A subsidiary of USX Corporation Environmentally aware for the long' run. October 18, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 Well Cuttings Samples Disposition KTU 32-7 and CLU 6, Cook Inlet, AK Sample Inventory Marathon Oil Company CLU 6 Box I Depths One set of 20' samples from 5500-8320' (TD) 1 5500' - 6100' 2 6100' - 6700' 3 6700' - 7260' 4 7260' - 7660' 5 7660' - 8000' 6 8000' - 8320' Sample Inventory Marathon Oil Company KTU 32-7 Box I Depths One set of 10' samples from 5700-9121' (TD) 1 5700' - 6040' 2 6040' - 6300' 3 6300' - 6580' 4 6580' - 6860' 5 6860' - 7220' 6' 7220' - 7500' 7 7500' - 7840' 8 7840' - 8120' 9 8120' - 8470' 10 ' 8470' - 8730' 11 8730' - 8920' 12 8920'. - 9121' 13 Core Chips Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Hand Delivered Received by: ~.._ ~~ Alaska .1~ Domestic',, oduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 21, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA CERTIFIED MAlL The following well logs are enclosed: Marathon Oil Company KTU 32-7 / Kenai Gas Field Print Reproducible KTU 32-7 - Array Induction, MCFL, Gamma Ray, Caliper, *Platform Express* - 8/26/00 ...... 1 ................. 1 KTU 32-7 - Density, Neutron, Gamma Ray, Caliper, *Platform Express* - 8/26/00 ................. 1 ................. 1 KTU 32-7 - Standard Digital Mudlog 2"=100' MD - 8/9/00 ...................................................... 1 ................. 1 velluTM KTU 32-7 - Standard Digital Mudlog 2"=100' TVD - 8/9/00 ..................................................... 1 ................. 1 vellum. Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Airbill # 1484663611 Received Date: RECEI D SEP 't000 N.aska 0ii. & llas Cons. coamissl.0n Anohorage A subsidiary of USX Corporation Environmentally aware for the long run. MARATHON 011_ COMPANY KTU #32-7 KENA I GA S FIEL D, PA D 4 I- 7 Section 7. T4N. R f I W, SM Kenai Peninsula, Alaska August 25, 2000 EPOCH TABLE OF CONTENTS MARATHON OIL COMPANY KTU #32-7 WELL RESUME 2 DRILLING AND FORMATION SUMMARY 3 LITHOLOGY SUMMARY 4 DAILY ACTIVITY SUMMARY 5 MUD RECORD 6 BIT RECORD 7 SURVEY RECORD 8 MORNING REPORTS WELL NAME: FIELD: REGION: LOCATION: BOROUGH: STATE: ELEVATION: APl NUMBER: OPERATOR: Operator Representatives: Company Geologist: CONTRACTOR: DRILLING RIG: Toolpusher: MUDLOGGING COMPANY: Logging Geologists: MUD COMPANY: Mud Engineers: MWD COMPANY: MWD Engineer: DIRECTIONAL COMPANY: Directional Driller: CEMENT COMPANY: WIRELINE COMPANY: Logging Engineer: WELL RESUME II I I MARATHON OIL COMPANY KTU 32-7 KENAi GAS FIELD KENAI PENINSULA, ALASKA 37' FNL, 4218' FWL SEC 7-T4N-RllW SM KENAI BOROUGH ALASKA RKB: 87.0' AMSL GL: 66.0' AMSL #50-133-20491-00 MARATHON OIL COMPANY OTIS WATKINS, DARRELL GREEN DAVID BRIMBERRY INLET DRILLING GLACIER DRILLING #1 GEORGE BREWSTER, MIKE LESLIE EPOCH WELL SERVICES, INC. CRAIG SILVA, RALPH WINKELMAN MI ROD MABEUS, WILLIE RINTOUL BAKER HUGHES INTEQ STEVE STURGES BAKER HUGHES INTEQ TOMM DUNN DOWELL SCHLUMBERGER SCHLUMBERGER KHEDJER MELLAH MARATHON OIL COMPANY KTU 32-7 DRILLING AND FORMATION SUMMARY PROSPECTUS The objectives of Marathon's KTU 32-7 well were to evaluate potentially gas productive sands in the Tyonek Formation. The surface location was the 41-7 pad within the Kenai Gas Field. The well was drilled directionally to the Southwest to evaluate these sands. BRIEF REVIEW OF ACTIVITY The drilling rig was MARATHON Glacier #1. Situated on Pad 41-7 In the Kenai Gas Field, the well was spudded on August 6, 2000, and reached a Total Depth of 9,121' M.D. (8,652' TVD) on August 25, 2000. 12 1/4" hole was drilled from surface to 1,510' MD, and 9 5/8" casing was set at 1,510". 8 ~" hole was drilled from 1,510' to 5,700' MD, and 7" casing was set at 5690' MD. 6 1/8" 1/2" hole was drilled to Total Depth at 9,121' MD. There were no major problems that impeded the drilling of KTU 32-7. There were no significant problems after reaching T.D. and completing the well. BRIEF DIRECTIONAL REVIEW KTU 32-7 was vertical to 540", where a kick off was initiated at Azimuth 270°. Hole Inclination Angle was built to a maximum 28.74° at 2,771'. The hole angle was held at 270-28° until 5,721' MD/5,321' TVD, and then the well path was directed toward vertical as per the well plan, eventually finishing at a projected 0.97° at 8,563' MD / 8,094' TVD. The wellpath's most northerly direction of Azimuth 334.30° was reached at 1,322' MD / 1,321 TVD, then turned gradually to the south and held in the 197°-202° range until 4932'/4500'TVD, and finally "walked" to the west at a planned 220° target direction as the hole drop was in progress. The well TD'd at a final azimuth of 221°. LOGGING PROCEDURES Epoch Well Services provided RIGWA TCH 2000TM Drilling Monitoring services and DMLT~ Mudlogging Service. Hydrogen flame ionization total gas and chromatograph detectors were employed to detect and analyze formation gases. Constant mud gas was generated by an air motor driven gas trap located at the shale shaker header box and extracted continuously from the trap to the unit by sample pumps. The gas trap was frequently cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated on a regular basis. Cuttings samples were collected at regular 10' intervals as directed by Marathon's sampling program. MARATHON OIL COMPANY KTU 32-7 LITHOLOGY SUMMARY SAND (5750'-5780'): MEDIUM TO DARK GRAY TO MEDIUM DARK GREENISH GRAY; FINE UPPER TO VERY COARSE LOWER; APPEARS FINING UPWARD IN MASSIVE SAND SECTIONS; POOR TO MODERATELY SORTED; LARGEST FRACTURETION IN COARSE LOWER RANGE; SUBROUND - SUBANGULAR, LARGER CLASTS COM ROUNDED; SUBDISCOIDAL TO SUBSPHERICAL; ENTIRELY DISAGGREGATED, SPOTTY CLAY PIECES WITH COM IMBEDDED SAND GRAINS; COMPOSITIONAL GRAYWACKE (>30% LITHICS); ESTIMATED 85- 95% LITHICS, 5-10% QUARTZ, TRACE FELDSPAR, TRACE OTHER FORMS SILICA; 90% OF THE LITHICS ARE DARK GRAY TO BLACK TO GREENISH BLACK MED GRADE META ARGILLITE ROCK FRAGMENTS; REMAINING LITHICS DOMINANTLY LOW GRADE METAGREENSTONE ROCK FRAGMENTS AND VARIOUS BLACK MAFIC MINERALS; NON - TRACE CALCITE. SAND (5785'-5810'): GENERALLY SAME AS ABOVE, BUT GREENISH BLACK TO BLACK, FINE LOWER TO MED LOWER, 95%+ LITHICS. TUFFACEOUS CLAYSTONE (5850' - 5920'): LIGHT GRAY TO LIGHT GREENISH GRAY WITH LIGHT BROWN SECONDARY HUES; VERY SOFT; STICKY; CLUMPY, ROUNDED, AMORPHOUS CUTTINGS; CLAYEY TO SILTY TEXTURE; EARTHY TO DULL LUSTRE; HYDROPHILIC AND EXPANSIVE WHEN HYDRATED; TRACE SCATTERED VERY THIN COAL / CARBONACEOUS LAMINATIONS AND PIECES; MODERATE TO GOOD ADHESIVENESS; MODERATE TO FAIR COHESIVENESS; NON CALCAREOUS. TUFFACEOUS CLAYSTONE (5920'- 5970'): CONTINUED SAME CHARACTERISTICS AS DESCRIBED ABOVE; NOTE INCREASE IN COAL AT 5950'; DARK BROWN TO BLACK, DARK DUSKY BROWN; FIRM TO HARD, OCCASIONALY PLIABLE AND WOODY; DENSE MATTE TEXTURE; DULL TO EARTHY LUSTRE; FAIR TO MODERATE PLANAR FRACTURETURE; PRESENT AS THIN INTERBEDS NEXT TO SANDY ZONES. SAND (6005' - 6040'): MEDIUM TO DARK GRAY OVERALL APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY MEDIUM TO DARK GRAYISH GREEN, TRACEANSLUCENT, LIGHT TO MEDIUM GRAY, BLACK; VERY FINE UPPER TO COARSE LOWER, DOMINANTLY MEDIUM LOWER; ANGULAR TO SUBANGULAR; UNCONSOLIDATED; POORLY SORTED; COMMON CLAYEY SUPPORTING MATRIX; NON CALCAREOUS; NOTE: COAL BECOMING DOMINANTLY BLACK; HARD TO BRITTLE; OCCASIONAL CONCHOIDAL FRACTURE. TUFFACEOUS SlLTSTONE (6010' - 6090'): LIGHT TO MEDIUM BROWN, OCCASIONAL DARK BROWN SECONDARY HUES; SOFT TO SLIGHTLY FIRM; ROUNDED, AMORPHOUS CUTTINGS; SILTY TEXTURE; DULL EARTHY LUSTRE; VERY CALCAREOUS; COMMON THIN LAMINATIONS AND PIECES OF BLACK CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE (6030' -6090'): CONTINUED SAME CHARACTERISTICS AS DESCRIBED ABOVE WITH INCREASING CALCAREOUSNESS WITH DEPTH AT 6030'. SAND (6120' - 6155'): TRANSLUCENT, LIGHT GRAY TO LIGHT GREENISH GRAY, DOMINANTLY MEDIUM TO DARK GRAY TO DARK GREENISH GRAY; FINE LOWER TO MEDIUM UPPER, DOMINANTLY MEDIUM LOWER WITH SCATTERED COARSE LITHS; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DOMINANTLY UNCONSOLIDATED WITH LIGHT GRAY, CLAYEY TO ASHY SUPPORTING MATRIX; SCATTERED BLACK CARBONACEOUS MATERIAL THROUGHOUT; COAL AT 6145'; BLACK; HARD TO BRITTLE; PLANAR TO SLIGHTLY CONCHOIDAL FRACTURE. TUFFACEOUS CLAYSTONE (6150' - 6220'): LIGHT GRAY TO LIGHT GREENISH GRAY, OCCASIONAL LIGHT BROWN TO LIGHT BROWNISH GRAY SECONDARY HUES; SOFT TO SLIGHTLY FIRM; VERY STICKY; CLUMPY, AMORPHOUS CUTTINGS; CLAYEY TO MATTE TEXTURE; DULL TO EARTHY LUSTRE; HYDROPHILIC; VERY EXPANSIVE WHEN HYDRATED; MODERATE TO GOOD COHESIVENESS AND ADHESIVENESS; SCATTERED BLACK CARBONACEOUS MATERIAL; NON TO SLIGHTLY CALCAREOUS. SAND (6180' - 6225'): TRACEANSLUCENT, LIGHT GRAY TO LIGHT GREENISH GRAY, DOMINANTLY MEDIUM TO DARK GRAY TO DARK GREENISH GRAY; FINE LOWER TO MEDIUM UPPER, DOMINANTLY MEDIUM LOWER WITH SCATTERED COARSE LITHS; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DOMINANTLY UNCONSOLIDATED WITH LIGHT GRAY, CLAYEY TO ASHY SUPPORTING MATRIX; SCATTERED BLACK CARBONACEOUS MATERIAL THROUGHOUT; COAL AT 6145'; BLACK; HARD TO BRITTLE; PLANAR TO SLIGHTLY CONCHOIDAL FRACTURE. TUFFACEOUS CLAYSTONE (6220' - 6275'): LIGHT GRAY TO LIGHT GREENISH GRAY, OCCASIONAL LIGHT BROWN TO LIGHT BROWNISH GRAY SECONDARY HUES; SOFT TO SLIGHTLYLY FIRM; VERY STICKY; CLUMPY, AMORPHOUS CUTTINGS; CLAYEY TO MATTE TEXTURE; DULL TO EARTHY LUSTRE; HYDROPHILIC; VERY EXPANSIVE WHEN HYDRATED; GOOD COHESIVENESS. ARGILLACEOUS CLAYSTONE (5700'-6300'): GENERALLY DARKER GRAY AND BRN COLORS, DENSER LOOKING, AND LACKING IN SHARDS; MOST IS TUFFACEOUS IN PART; OFTEN SLIGHTLY TO MODERATELY FRM AND OCCASIONAL SLIGHTLY TO MODERATELY BRIT; MOST IS MASSIVE AND STRUCTURELESS, BUT LOCALLY IS SLIGHTLY SHALEY IN PART; CLAYEY TO SLIGHTLY SILTY TO DENSE MATTE TEXTURES; DULL TO EARTHY LUSTRE; COM HAS THIN CA~{BONACEOUS LAMINATIONS AND/OR PARTICLES; NON CALCAREOUS. SAND (6295'-6465'): ONLY VERY MINOR VARIATIONS IN AVERAGE GRAIN SIZE; LARGE SAND SECTIONS SHOW FINING UPWARD; NO SIGNIFICANT DIFFERENCES IN THE CHARACTER OF SUCCESSIVE SECTIONS; MED DARK GRAY TO DARK GRAY, COM WITH MED TO DARK GREENISH GRAY SECONDARY HUES, LOCALLY DARK GREENISH GRAY TO GREENISH BLACK; FINE LOWER TO VERY COARSE LOWER, TRACE GRANULES, SPOTTY FRACTURES, GRADATIONAL TO SILTSTONE; MODERATE SORTING IN MEDIUM LOWER TO COARSE LOWER RANGE; 80% SUBROUNDED-SUBANGULAR, 10% ANGULAR, 10% ROUNDED; MOSTLY SUBDISCOIDAL, LARGER CLASTS MORE OFTEN SUBSPHERICAL; ALMOST ENTIRELY DISAGGREGATED, BUT MANY LUMPS OF TUFFACEOUS CLAYSTONE HAVE SAND GRAINS; TRACE PIECES OF FINE GRAIN SUPPORTED SANDSTONES WITH DOMINANTLY SILICA CEMENTATION/RARE CALCCAREOUS CEMENT; COMPOSITIONAL GRAYWACKE TO LITHIC ARENITE; NOTE THAT THE FINER SAND HAS A HIGHER % OF QUARTZ; ESTIMATED 30-70% QUARTZ (AND COLORLESS TRANSPARENT VOLC GLASS), 70-25% LITHICS, TRACE-5% FELDSPAR, TRACE-5% CHERT, TRACE-5% CHALCEDONY AND CRYTOXLN SILICA; BLACK MAFICS INCLUDED WITH LITHICS; LITHICS DOMINANTLY DARK GRAY TO DARK GREENISH GRAY MED GRADE META ARGILLITE-PHYLLITEROCK FRAGS; SPOTTY LOW GRADE METAGREENSTONE ROCK FRAGS; ESTIMATED 70-80% OF QUARTZ IS COLORLESS OR VERY PALE COLORED AND TRACEANSLUCENT, REMAINING IS COLORLESS TRANSPARENT; SPOTTY TO LOCALLY COM PALE BROWN AND TRACEANSLUCENT- TRANSPARENT CHERT OR OTHER SILICA FORM. TUFFACEOUS CLAYSTONE (6275'-6630'): LIGHT GRAY TO LIGHT BRNISH GRAY, OCCASIONAL MOTTLED WITH VERY LIGHT GRAY STREAKY PATCHES, OCCASIONAL FINET BLUISH GRAY OR GREENISH GRAY SECONDARY HUES; SOFT TO SLIGHTLY FIRM TO SLIGHTLY BRITTLE; CLAYEY TO ASHY TO VARIOUS SOFT MATTE TEXTURES; SPOTTY TO VERY COMMON VIS GLASS SHARDS; SOFT GLASSY TO DULL TO MICROSPARKLY LUSTRE; RARE PIECES DISPLAY A ROCK FABRIC OF DENSE GLASSY PARTICLES; SOFTESTIMATED PIECES ARE SLIGHTLY TO MODERATELY SOLUBLE; APPEARS BOTH HYDROPHILIC AND HYDROPHOBIC IN PART; MODERATE TO OCCASIONALLY GOOD ADHESIVENESS; MODERATE TO OCCASIONAL POOR COHESIVENESS. SAND (6465'-6665'): GENERALLY ERALLY SAME CHARACTERISTICS AS DESCRIBED ABOVE; NOTE THAT THE TYPE SAND IS LESS OFTEN COMPOSITIONAL GRAYWACKE (>30% LITHICS) AND MORE OFTEN LITHIC OR SUBLITHIC ARENITE; CONTINUED FINING UPWARD THRU MAJOR SECTIONS; LOCAL ZONES WITH TRACE MODE OF CONGLOMERATE GRANULES/PEBBLES; BECOMING ANGULAR OVERALL, DOMINANTLY MODE IS SUBANGULAR TO SUBROUNDED. COAL/CARBONACEOUS SHALE (6650-6690'): BLACK TO BROWNISH BLACK TO VERY DUSKY BROWN; LOW GRADE COAL, LIGNITE, CLOSELY GRADATIONAL TO CARBONACEOUS SH; MOSTLY BRITTLE AND FRAGILE, OCCASIONAL PIECES ARE TOUGH AND BRITTLE; MANY CUTTINGS FRAGS HAVE THIN ALTERNATING LAYERS OF BLACK COAL AND BRN CARBONACEOUS SH; GENERALLY DULL TO DENSE EARTHY LUSTRE, RARE RESINOUS LUSTRE; IRREGULAR PLANAR FRACTURETURE, SOME COAL HAS IRREGULAR BLOCKY FRACTURET; COM MICROTHIN COAL/CARB SHALE LAMINATIONS IN THE OTHER LITHOLOGIES. TUFFACEOUS CLAYSTONE (6650'-6850'): LIGHT GRAY TO LIGHT BRNISH GRAY, OCCASIONAL MOTTLED WITH VERY LIGHT GRAY STREAKY PATCHES, OCCASIONAL FINET BLUISH GRAY OR GREENISH GRAY SECONDARY HUES; SOFT TO SLIGHTLY FIRM TO SLIGHTLY BRITTLE; CLAYEY TO ASHY TO VARIOUS SOFT MATTE TEXTURES; SPOTTY TO VERY COMMON VIS GLASS SHARDS; SOFT GLASSY LUSTRE; SAND (6775'- 6810'): MEDIUM TO DARK GREENISH GRAY, TRACEANSLUCENT, DARK GREEN; FINE UPPER TO MEDIUM UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DOMINANTLY UNCONSOLIDATED TO LOOSELY CONSOLIDATED WITH LIGHT GRAY, CLAYEY SUPPORTING MATRIX; NOTE: SANDSTONE; DARK GRAY TO GRAYISH BLACK, SLIGHTLY SALT AND PEPPER APPEARANCE; VERY FINE GRAIN, GRADING TO SILT; MODERATELY HARD TO HARD WELL CONSOLIDATED; WELL SORTED; VERY CALCAREOUS. TUFFACEOUS CLAYSTONE (6800' - 6895'): LIGHT GRAY TO LIGHT BROWNISH GRAY WITH VERY LIGHT BROWN SECONDARY HUES; SOFT; PLIABLE; STICKY; ROUNDED, CLUMPY, AMORPHOUS CUTTINGS; CLAYEY TO SLIGHTLY ASHY/ GRITTY TEXTURE; DULL, EARTHY LUSTRE; MODERATE TO GOOD ADHESIVENESS AND COHESIVE NESS; NON CALCAREOUS; COMMON THIN COAL LAMINATIONS/PIECES THROUGHOUT. SAND (6895' -6925'): CONTINUED SAME CHARACTERISTICS AS DESCRIBED ABOVE WITH INCREASE IN MICROTHIN TO THIN COAL LAMINATIONS. TUFFACEOUS SlLTSTONE (6940' - 6960'): MEDIUM TO DARK GRAY TO GRAYISH BLACK; MODERATELY FIRM TO SLIGHTLY BRITTLE; SILTY TO SLIGHTLY GRITTY TEXTURE; EARTHY TO MICROSPARKLY LUSTRE; NON CALCAREOUS; NOTE: ABUNDANT MICROTHIN CARBONACEOUS/COAL LAMINATIONS THROUGHOUT; TRACE CALCITE PIECES. SAND (6960' - 7070'): LIGHT TO MEDIUM GRAY, MEDIUM TO DARK GRAY TO DARK GREENISH GRAY; FINE UPPER TO COARSE UPPER, DOMINANTLY MEDIUM LOWER; ANGULAR TO SUBROUNDED, DOMINANTLY SUBANGULAR; MODERATELY SORTED; DISAGGREGATED; COM CLAY PIECES WITH IMBEDDED SAND GRAINS, MANY ARE CLOSELY GRADATIONAL TO A VERY CLAYEY SANDSTONE; MANY SAND-CLY/CLY-SAND PIECES HAVE MICRO THIN COAL LAMINATIONS THROUGHOUT; MORE MASSIVE SAND SECTIONS DISPLAY FINING UPWARD; COMPOSITION RANGES FROM SUBLITHIC ARENITE TO COMPOSITIONAL GRAYWACKE (>30% LITHICS); ESTIMATED 50-80% QUARTZ (AND GLASS), TRACE-5% FELDSPAR, TRACE-15% CHERT/CHALCEDONY/OTHER FORMS SILICA, 15-65% LITHICS (+ MAFIC MNRLS); QUARTZ IS 65% TRACEANSLUCENT, 35% TRACEANSPARENT. TUFFACEOUS CLAYSTONE (6900'-7300'): LIGHT GRAY TO LIGHT BRNISH GRAY, OCCASIONAL MOTTLED WITH VERY LIGHT GRAY STREAKY PATCHES, OCCASIONAL FINET GRAYISH ORANGE PINK SECONDARY HUES; SOFT TO SLIGHTLY FIRM TO SLIGHTLY BRITTLE; CLAYEY TO ASHY TO VARIOUS SOFT MATTE TEXTURES; SPOTTY TO VERY COMMON VIS GLASS SHARDS; SOFT GLASSY TO DULL TO MICROSPARKLY LUSTRE; RARE PIECES DISPLAY A ROCK FABRIC OF DENSE GLASSY PARTICLES; SOFTESTIMATED PIECES ARE SLIGHTLY TO MODERATELY SOLUBLE; APPEARS BOTH HYDROPHILIC AND HYDROPHOBIC IN PART; MODERATE TO OCCASIONALASIONALLY GOOD ADHESIVENESS; MODERATE TO POOR COHESIVENESS. SAND/SANDSTONE (7100'-7220'): MEDIUM TO MEDIUM DARK GRAY; LOCALLY COM STRONG GREENISH GRAY SECONDARY HUES; FINE LOWER TO COARSE LOWER; TRACE GRAINS TO GRANULE SIZE; MODERATELY SORTED IN MEDIUM RANGE; DOMINANTLY SUBANGULAR AND SUBDISCOIDAL; MIX OF MATRIX AND GRAIN SUPPORTED; COM "DIRTY" GRAIN SUPPORTED WITH CALCITE CEMENTATION; DOMINANTLY LITHIC ARENITE; NOTE LOCAL INCREASE IN CHERT FRACTURETION TO 15-20%;. LITHICS AREDOM DK GRAY ARGILLITE/PHYLLITEROCK FRAGMENTS, BUT GREENSTONE LITHICS ARE BECOMING MORE ABNT; NOTE COM FINE CLASTIC COAL FRAGS. COAL/CARBONACEOUS SHALE (7200'-7290'): BLACK TO BROWNISH BLACK TO VERY DUSKY BROWN; LIGNITE, CLOSELY GRADATIONAL AND VERY THINLY INTERBEDDED WITH CARBONACEOUS SH; BRITTLE TO VERY FIRM; FRAGILE TO TOUGH; SMOOTH TO DENSE MATTE TEXTURE; DULL TO VERY IDENSE EARTHY TO OCCASIONAL RESINOUS LUSTRE; DOMINANTLY IRREGULAR PLANAR FRACTURETURE, OCCASIONAL IRREGULAR BLOCKY FRACTURETURE; COM CUTTINGS PIECES WITH ALTERNATING MICROTHIN COAL AND CARB SHALE LAMINATIONS; COM CARB SHALE WITH COAL PARTICLES. SAND/SANDSTONE (7300' - 7325'): MEDIUM TO MEDIUM DARK GRAY TO DARK GREENISH GRAY, SCATTERED TRACEANSLUCENT AND LIGHT GRAY; FINE UPPER TO MEDIUM UPPER; MODERATELY WELL SORTED; SUBANGULAR TO SUBROUNDED; LOOSELY CONSOLIDATED; NON CALC; TRACE CALCITE PIECES; ABUNDANT FINE CLASTIC COAL FRAGMENTS; MOSTLY MATRIX SUPPORTED WITH MIX OF CLAY, SILT, SILICA; LITHIC ARENITE TO COMPOSITIONAL GRAYWACKE. SAND (7370'-7385'): GENERALLY ERALLY SAME AS ABOVE BUT ALMOST ALL DISAGGREGATED; FINING UPWARD; NOTE THIN BASAL ZONE IS COARSE TO VERY COARSE. COAL/CARBONACEOUS SHALE (7385'-7485'): BLACK TO BROWNISH BLACK TO VERY DUSKY BROWN; LIGNITE, CLOSELY GRADATIONAL AND VERY THINLY INTERBEDDED WITH CARBONACEOUS SH; BRITTLE TO VERY FIRM; FRAGILE TO TOUGH; SMOOTH TO DENSE MATTE TEXTURE; DULL TO VERY DENSE EARTHY TO OCCASIONAL RESINOUS LUSTRE; DOMINANTLY IRREGULAR PLANAR FRACTURETURE, OCCASIONAL IRREGULAR BLOCKY FRACTURETURE; COM CUTTINGS WITH ALTERNATING MICROTHIN COAL AND CARBONACEOUS SHALE LAMINATIONS; COM CARBONACEOUS SHALE WITH COAL PARTICLES; COM COAL PIECES WITH OUTGASSING BUBBLES; TRACE PALE YELLOW AMBER GRAINS. SANDSTONE/SAND (7480'-7550'): LIGHT MED TO DARK GRAY WITH VERY STRONG GREENISH GRAY SECONDARY HUES; FINE LOWER TO COARSE LOWER; TRACE GRANULES; MODERATELY SORTED IN MEDIUM TO COARSE RANGE; MOSTLY SUBANGULAR AND SUBDISCOIDAL; MIX OF MATRIX AND GRAIN SUPPORTED; COMMON "DIRTY" GRAIN SUPPORTED WITH BOTH SILIC AND CALC CEMENTATION; ABNT MATRIX SUPPORT WITH TUFFACEOUS CLAY AND SILT; CLAY-RICH SUBLITHIC TO LITHIC ARENITE; NOTE THAT COMPOSITION ROUGHLY APPEARS TO VARY WITH GRAIN SIZE, AS SANDSTONE BECOMES FINER THE PERCENTAGE QUARTZ FRACTION INCREASES; GREENSTONE LITHICS ARE BECOMING MORE COMMON; VERY COM CLASTIC SAND-SIZE COAL FRAGS; RARE PIECES OF CARBONACEOUS SANDSTONE. COAL/CARBONACEOUS SHALE (7540'-7630'): BLACK TO BROWNISH BLACK TO VERY DUSKY BROWN; LIGNITE, CLOSELY GRADATIONAL AND VERY THINLY INTERBEDDED WITH SH; BRITTLE TO VERY FIRM; FRAGILE TO TOUGH; SMOOTH TO DENSE MATTE TEXTURE; DULL TO VERY DENSE EARTHY TO OCCASIONAL RESINOUS LUSTRE; DOMINANTLY IRREGULAR PLANAR FRACTURE, OCCASIONAL IRREGULAR BLOCKY FRACTURETURE; COM COAL PIECES WITH OUTGASSING BUBBLES; TRACE AMBER. SAND (7640' - 7685'): NOTE DISTINCTIVE COLOR CHANGE FROM ALL PREVIOUS SAND ZONE LIGHT GRAY OVERALL APPEARANCE WITH OCCASIONAL SALT AND PEPPER, INDIVIDUAL GRAINS DOMINANTLY TRACEANSLUCENT TO VERY LIGHT GRAY, COM COLORLESS AND TRACEANSPARENT; SCATTERED BLACK AND DARK GRAY; FINE UPPER TO MEDIUM UPPER, RARE COARSE PIECES; SUBANGULAR TO SUBROUNDED; WELL SORTED; DISAGGREGATED TO WEAKLY CONSOLIDATED WITH LIGHT GRAYISH WHITE, CLAYEY, ASHY, SUPPORTING MATRIX; TRACE TO SPOTTY GRAIN SUPPORTED CALCITE ANDSILICA CEMENTED. TUFFACEOUS CLAYSTONE (7690' - 7750'): LIGHT GRAY TO LIGHT BROWNISH GRAY WITH VERY LIGHT BROWN SECONDARY HUES; VERY SOFT TO SLIGHTLY FIRM; SLIGHTLY STICKY TO CLUMPY; ROUNDED, AMORPHOUS CUTTINGS; CLAYEY TO SLIGHTLY GRITTY TEXTURE; DULL TO EARTHY LUSTRE; HYDROPHILIC; VERY EXPANSIVE WHEN HYDRATED; FAIR COHESIVENESS AND FAIR TO GOOD ADHESIVENESS; NON CALCAREOUS; VERY SANDY IN PART. COAL (7700' - 7760'): BLACK, OCCASIONALASION-ALY DARK DUSKY BROWN TO DARK BROWNISH BLACK; VERY FIRM TO SLIGHTLY HARD, BRITTLE; BLOCKY TO PLANAR CUTTINGS; SMOOTH TO DENSE MATTE TEXTURE; EARTHY TO OCCASIONALY RESINOUS LUSTRE; COMMON COAL PIECES WITH OUTGASSING BUBBLES; TRACE AMBER; SCATTERED WHITE VOLCANIC ASH. SANDSTONE (7770' - 7850'): SALT AND PEPPER APPEARANCE, DOMINANTLY LIGHT GRAY TRACEANSLUCENT TO LIGHT GREENISH GRAY FOR INDIVIDUAL GRAINS, COMMON BLACK INCLUSIONS; VERY FINE GRAIN; MODERATELY HARD BRITTLE; WELL SORTED; SUBANGULAR TO SUBROUNDED; WELL CONSOLIDATED WITH WHITE TO VERY LIGHT YELLOWISH BROWN CEMENT; VERY CALCAREOUS SUPPORTING MATRIX; COMMON WHITE TO GRAYISH BROWN VOLCANIC TUFFS. TUFFACEOUS CLAYSTONE (7820' - 7900'): LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; SILTY IN PART; SLIGHTLY STICKY; CLUMPY, AMORPHOUS CUTTINGS; SILTY TO GRITTY TEXTURE; DULL TO EARTHY LUSTRE; HYDROPHILIC; VERY EXPANSIVE WHEN HYDRATED; FAIR TO GOOD COHESIVENESS; FAIR ADHESIVENESS; NON CALCAREOUS; PRESENT AS SUPPORTING MATRIX FOR SAND; ABUNDANT VOLCANIC ASH THROUGHOUT. VOLCANIC ASH (7630'-8000'): VERY CLOSELY GRADATIONAL TO THE' TUFFACEOUS CLAYSTONE DESCRIBED ABOVE; VERY LIGHT GRAY TO WHITE, OCCASIONAL VERY LIGHT GRAYISH BROWN; SOFT TO SLIGHTLY FRM; ASHY TO MIXED CLAY-ASH TO SOFT MATTE TEXTURES; SOFT GLASSY AND MICROSPARKLY LUSTRES; ABNT VIS GLASS SHARDS; SPTTY BLACK MICRO MAFIC MNRLS; EVIDENT VITROCLASTIC ORIGIN DESPITE BEING REWORKED. SAND (7950'-7980'): LIGHT GRAY TO VERY LIGHT GRAY; COM WITH FINET GREENISH GRAY SECONDARY HUES; GENERALLY HAS A "GRAYISH" SALT AND PEPPER APP WITH PRESENCE OF BLACK MAFIC MINERALS; VF UPPER TO MED UPPER; MODERATELY WELL-WELL SORTED IN FINE UPPER RANGE; 99% SUBANG-ANG AND SUBDISCOIDAL-DISCOIDAL; TRACE EUH-SBHED QUARTZ GRS; DISAGGREGATED; TRACE VOLC ASH MTRX SUPPORTED SS; SUBLITHIC ARENITE; ESTIMATED 70-85% QUARTZ (AND VOLC GLASS), TRACE-5% FELDSPAR, 5-15% CHERT/CHALCEDONY/OTHER FORMS OF SILICA; 10-20% LITHICS DOMINANTLYINATED BY LO GRADE META GREENSTROCK FRAGMENTS. VERY ASHY SANDSTONE AND SILTSTONE (8000'-8100'): NOTE THAT IN THIS INTERVAL THE CONSOLIDATED SS, VOLC ASH, AND TUFFACEOUS SILTSTONE ARE ACTUALLY A SINGLE LITHOLOGY WITH MINOR GR SIZE AND SUPPORTING MATRIX VARIATIONS; THE VF-FINE SS OCCASIONAL HAS SIZE DECR INTO THE SLT RANGE, AND THE SUPPORTING VOLC ASH MTRX OCCASIONAL IS OCCASIONAL > THAN 50% TOTAL VOLUME; VERY LIGHT GRAY TO WHITE; VF LOWER TO FINE UPPER; MOSTLY WELL SORTED; SUBANGULAR-SUBROUND; SPHERICAL-SUBDISCOIDAL; ASHY QUARTZ ARENITE TO SUBLITHIC ARENITE; NOTE 30-70% OF GRAINS ARE COLORLESS AND TRACEANSPARENT AMORPHOUS MACROSHARDS OF VOLCANIC GLASS. TUFFACEOUS SHALE (8090'-8160'): LIGHT MED GRAY TO MED DARK GRAY, GENERALLY WITH VERY STRONG BRNISH GRAY SECONDARY HUE, OCCASIONAL ALSO WITH FINET BLUISH GRAY HUE; SOFT TO SLIGHTLY FRM AND VERY SLIGHTLY BRIT; POORLY DEVELOPED FISSILITY, BUT IMPERFECT PARALLEL SEPARATION DISTINGUISHESSHALEFROM THE MORE MASSIVE CLAYST; CLYEY-ASHY TEXT; EARTHY LUSTRE. COAL (8170' - 8225'): BLACK, DARK DUSKY BROWN TO DARK BROWNISH BLACK; HARD; BRITTLE; PLATY TO BLOCKY; COMMON CONCHOIDAL FRACTURETURE, DOMINANTLY PLANAR FRACTURETURE; SMOOTH TO DENSE MATTE TEXTURE; DULL EARTHY TO OCCASIONALY RESINOUS LUSTRE; ABUNDANT COAL PIECES WITH OUTGASSING BUBBLES; TRACE AMBER; SCATTERED VOLCANIC TUFFS THROUGHOUT; NO SAMPLE FLUOR. SAND/SANDSTONE (8215' -8280'): LIGHT TO MEDIUM GRAY, MODERATE SALT AND PEPPER OVERALL APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY TRACEANSLUCENT, LIGHT TO MEDIUM GRAY, DARK GRAY TO BLACK; DOMINANTLY VERY FINE LOWER; MODERATELY WELL SORTED; LOOSELY CONSOLIDATED WITH WHITE, ASHY/CLAYEY SUPPORTING MATRIX; VERY CALCAREOUS; SUBANGULAR'TO SUBROUNDED; ABUNDANT WHITE TO LIGHT GRAY VOLCANIC ASH; ABUNDANT THIN COAL BEDS THROUGHOUT. TUFFACEOUS CLAYSTONE (8205' -8330'): LIGHT BROWN TO LIGHT BROWNISH GRAY, LIGHT GRAY SECONDARY HUES; SOFT TO FIRM; OCCASIONALY STICKY; SILTY IN PART; CLUMPY AMORPHOUS CUTTINGS; EXPANSIVE WHEN HYDRATED; FAIR ADHESIVENESS; FAIR TO GOOD COHESIVENESS; SILTY TO SLIGHTLY GRITTY TEXTURE; EARTHY TO DULL LUSTRE; VERY CALCAREOUS; ABUNDANT VOLCANIC ASH; TRACE CALCITE PIECES; NO SAMPLE FLUOR. COAL (8350' - 8325'): DARK DUSKY BROWN TO BLACK; VERY FIRM TO HARD; BRITTLE; BLOCKY TO IRREGULAR CUTTINGS; SMOOTH TO DENSE MATTE TEXTURE, OCCASIONALY SILTY IN PART; DULL TO EARTHY LUSTRE, OCCASIONALLY RESINOUS; ABUNDANT OUTGASSING BUBBLE VISIBLE; TRACE AMBER; COAL OCCASIONALY GRADING TO A VERY DARK BROWN CARBONACEOUS SHALE. SILTSTONEI CLAYSTONE (8390' - 8400'): NOTE COLOR CHANGE FROM A LIGHT GRAY TO A MEDIUM TO DARK BROWN; SOFT TO SLIGHTLY FIRM; CLUMPY; ROUNDED AMORPHOUS CUTTINGS SILTY TEXTURE; DULL EARTHY LUSTRE; NON CALCAREOUS; TRACE TUFFS; TRACE CALCITE. COAL (8455' - 8485'): BLACK WITH DARK DUSKY BROWNISH BLACK SECONDARY HUES; VERY FIRM TO MODERATELY HARD; BRITTLE; BLOCKY TO OCCASIONALY PLATY CUTTINGS; PLANAR FRACTURETURE; SMOOTH TO DENSE MATTE TEXTURE; RESINOUS TO EARTHY LUSTRE; VERY ABUNDANT VISIBLE OUTGASSING BUBBLES; TRACE AMBER. SAND (8495' -8555'): VERY LIGHT GRAY TO LIGHT GRAY, SCATTERED LIGHT BRNISH YELLOW AND PALE GREENISH GRAY LITHICS; VERY FINE UPPER TO RARE COARSE LOWER, DOMINANTLY FINE LOWER; ANGULAR TO SUBROUNDED, DOMINANTLY SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED TO WEAKLY CONSOLIDATED WITH VOLC ASH/CLAY SUPPORTING MATRIX; VERY CALCAREOUS; COM MOTTLED MIX OF ASH AND CALCITE; SUBLITHIC ARENITE; QUARTZ IS 70% COLORLESS OR LIGHT COLORED AND TRACEANSLU, 30% TRACEANSP. SANDSTONE/SAND (8530'-8580'): VERY LIGHT GRAY TO LIGHT GRAY; GENERALLY SALT AND PEPPER APP; VF LOWER TO MED LOWER; MODERATELY WELL SORTED IN V F UPPER TO FINE UPPER RANGE; SUBROUND-SUBANGULAR, SUBSPHERICAL; LOCALLY VERY SILTY; CONSOL PIECES ARE VOLC ASH MATRIX SPPRTD, AND CALC CMTD GR SPPRTD; SOME FINER SS IS VERY CALCAREOUS; ASHY LITHIC QUARTZ ARENITE TO SUBLITHIC ARENITE; 5-20% LITHICS DOMINANTLY BY GRAYSH GRN GREENSTROCK FRAGMENTS. COAL (8612'-8621'): VERY MASSIVE LOOKING; BLACK; SUBBITUMINOUS; BRITTLE; TOUGH; IRREGULAR SBBLOCKY TO SBPLTY FRAGS; IRREGULAR SUBPLANAR FRACTURETURE, OCCASIONAL FINET BIRDEYE; SMOOTH TEXT; RESINOUS LUSTRE; TRACE AMBER. SAND (8630'-8655'): VERY LIGHT GRAY; APPEARS SALT AND PEPPER WITH BLACK MAFICS; FINE LOWER TO MED LOWER, RARE GRS > COARSE; FINING UPWARD; MODERATELYWELL SORTED IN FINE UPPER; SUBANGULAR>SUBROUND>ANG; SBSPHER>SBDISCOIDAL; DISAGGTD; LITHIC QUARTZ ARENITE TO SBLITHIC ARENITE; ESTIMATED 75-90% QUARTZ, TRACE- 5% FELDSPAR, TRACE-10% CHALCDNY/CHRT/OTHER SILIC, 10-15% BLACK MAFIC MNRLS AND (DOM GRNST) LITHICS; 20-35% OF QUARTZ FRACTURETION IS COLORLESS AND TRACEANSPARENT VOLC GLASS. TUFFACEOUS CLAYSTONE (8730' -8785'): LIGHT BROWN TO LIGHT GRAYISH BROWN; SOFT TO SLIGHTLY FIRM; ROUNDED, AMORPHOUS CUTTNGS; SILTY IN PART; EXPANSIVE WHEN HYDRATED; CLAYEY TO SLIGHTLY GRITTY TEXTURE AT TIMES; DULL, EARTHY LUSTRE; FAIR ADHESIVENESS; POOR COHESIVENESS; MODERATELY CALCAREOUS; SCATTERED YELLOWISH WHITE, WAXY TUFFS. SAND (8720' -8790'): CONTINUED SAME CHARACTERISTICS AS DESCRIBED ABOVE; TRACE WAXY, BROWNISH YELLOW TO LIGHT GRAY TUFFS. COAL (8791' - 8835'): BLACK, WITH DARK DUSKY BROWN TO BROWNISH BLACK SECONDARY HUES; VERY FIRM TO HARD; BRITTLE; IRREGULAR SUBBLOCKY TO SUBPLATY CUTTINGS DOMINANTLY PLANAR TO SUBPLANAR FRACTURETURE, OCCASIONAL CONCHOIDAL AND BIRDEYE FRACTURE; SMOOTH TO DENSE MATTE TEXTURE; RESINOUS TO OCCASIONALY EARTHY LUSTRE; COMMON VISIBLE OUTGASSING BUBBLES; TRACE AMBER. SAND/SANDSTONE (8840'-8850'): LIGHT YELISH BRN OVERALL FROM FRAGMENTS OF (CLASTIC) CALC TUFF; TRACE SPL PIECES SHOW MICROTHIN INTBDDG OF SS AND TUFF SLTST OR TUFF SHALE; MODERATELY WELL SORTED IN FINE UPPER-MED LOWER RANGE. SANDSTONE/SAND (8870'-8910'): LIGHT GRAY-LT MED GRAY; GENERALLY SALT ANDPEPPER APP; PROM FINING UP; VF UPPER TO GRANULE; WELL SORTED IN FINER UPPER ZONE, MODERATELY TO POORLY SORTED IN COARSE BASAL PART; MOSTLY SUBANGULAR AND SBDISCOIDAL; DISAGGTD AND CONSOL ASH MTRX SPPRTD; SUBLITHIC TO LITHIC ARENITE; 15-25% METALITHICS AND BLACK MAFICS SANDSTONE/SAND (8915'-8960'): GENERALLY SAME AS ABOVE BUT LACKS FINING UPWARD; MANY CTTGS PIECES DISPLAY MICROTHIN INTBDDG OF TUFF SLTST AND SS; COM THN ASHY ZONES. COAL (8960'-8990'): BLACK; BRITTLE AND TOUGH; LO GRADE, LIGNITE TO SUBBIT; BOTH GRADING TO, AND INTERLAMINATED WITH BROWN TO DUSKY BROWNCARBONACEOUS SH; SMOOTH TO DENSE MATTE TEXT; RESINOUS LUSTRE; IRREGULAR PLANAR FRACTURETURE; TRACE AMBER. SAND (9005' - 9035'): LIGHT TO MEDIUM GRAY OVERALL APPEAI:~NCE, INDIVIDUAL GRAINS DOMINANTLY TRACEANSLUCENT TO LIGHT GRAY, COMMON DARK GRAY TO GRAYISH GREEN LITHS, SCATTERED BLACK LITHS; DOMINANTLY VERY FINE LOWER; ANGULAR TO SUBANGULAR; WELL' SORTED; LOOSELY TO UNCONSOLIDATED; COMMON CALCITE PIECES; ABUNDANT WHITE TUFFS AT 9030'. SAND/SANDSTONE (9055'-9070'): LIGHT TO MEDIUM GREENISH GRAY; MODERATELYWELL SORTED IN FINE LOWER-MED LOWER RANGE; SUBANGULAR-ANG, SBDISCOIDAL-DISCOIDAL; DISAGGTD TO WEAK CALC CMTD GR SUPPORTD; LITHIC ARENITE; 20-25% LITHICS DOMINANTLY BY GREENSTROCK FRAGMENTS. SANDSTONE/TUFFACEOUS ORIGIN ROCKS (9070' - 9114') NOTE MANY LARGE CUTTINGS PIECES AFTER 9030' DISPLAy MIXED MICROTHIN INTERBEDDING OF TWO OR MORE CURRENT LITHOLOGIES. COAL (9114'-9121'): BLACK; BRITTLE AND TOUGH TO MARGINAL HARD; SMOOTH TEXT; RESINOUS LUSTRE; IRREGULAR SBBLOCKY FRACTURETURE; PROM MICROTHIN LAMINAR BANDS; TRACE AMBER; ABNT VIS BUBBLES FROM OUTGASSING. MARATHON OIL COMPANY KTU 32-7 DAILY CHRONOLOGY 8/04/2000: Finish picking up Top Drive. Change saver sub to 4 W'IF connection and install end bell guide for 5" HWDP. Install casing stabbing board. Install purge air for Top Drive. Rig up flow line and jet line. Install rig floor mud manifold. Hang kelly hose and cement hose. Install trip tank flow line. Finish installing diverter line. Work on water line to tanks from water well. Spot second water tank. Install Flowshow in flow line. Install mouse hole. Fold up derrick windwalls. Install geolograph line. Prepare to pick up drill pipe. 810512000: Rig accepted for well work on KBU 33-6 at 00:01Hrs on 4~28~2000. Set mudlogging unit. Strap drill pipe. Hold PJSM. Pick up 4" drill pipe and stand back same in derrick. Strap 5" HWDP. Function test annular and knife valves as required per AOGC. Pick up 5" drill pipe and stand back same in derrick. Pick up and make up BHA#1. Tag botto~ at 46'. Attempt to break circulation. Trouble shoot mud pump PLC. Fill hole. Break circulation. Check for leaks. Drill from 46' to 67'. Circulate and clean hole. Jet flowline. Orient MWD and make connection. Trouble shoot mud pump PLC and find bad connection in plug. Drill from 67' to 129'. Conveyer plugged up. Control drill from 129' tO 217'. 8/06/2000 Work on Top Drive. Attempt to break out stand of HWDP. Shuttle valve on carrier not shifting to give correct hydraulic pressure for task at hand. Repaired valve. Control drill from 129' to 525'. Manage fluid losses at shakers with gravel washing process. Drill ahead from 525' to KOP at 600'. Rotate and slide as needed to build and control angle and direction. Drill ahead to 941'. Circulate hole clean. Change out Top Drive saver sub, end bell guide, and elevator inserts. Saver sub was galled on the first make up and had to be changed out a second time. Drill from 941' to 1004'. 810712000: Drill ahead sliding from 1004' to 1037', and back ream hole section. Lay down 2 bad joints of 4" drill pipe. Pump up Top Drive compensator. Hold pit drill. Rotate drill from 1037' to 1068'. Slide drill from 1068' to 1088'. Pump Motor #2 went down due to high temperature. Work pipe and circulate on Pump #1. Start Pump #2, and run and inspect same. Drill from 1088' to 1200', sliding for 3.25 hours and rotating for 1.5 hours. Blow hydraulic drive hose off Pump #1. Circulate and pads to repair Pump #1. Change liners in pumps to 5 W'. Work on mud system Install new hose and test run Pump #1. · 8/08/2000. MWD failed to generate a pulse. Surge, rotate, and jar on MWD tool. Sweep with 10 barrels of water but still no pulse. Back ream 5 stands. Lay down and replace two bad joints of 4" HT-38 drill pipe while POOH for MWD inspection. Circulate bottoms up and pump dry job. Continue POOH. Break down and lay down MWD tool. Retrieve damaged Pulsar. Pulsar in 3 pieces. Break bit and motor. Inspect for damage and fragmented pulsar parts. Orient motor and make up BHA. RIH and test MWD tool. Continue RIH to bottom, lnteq working on computer software problem to achieve an MWD tool face. Drill ahead and slide as needed from 1200' to 1370'. Slide time at 4.75 hours and rotating time at 1 hour. Circulate hole clean. Change out Top Drive saver sub. Service rig. Drill ahead from 1370'. 810912000: Continue drilling to 1468'. Slide time 3.75 hours and rotating time 0.75 hours. Ream and back ream to clean the hole. Drill from 1468' to 1503'. Pump high viscosity nut plug sweep to clean hole. Rotating time 0.5 hours. Drill ahead from 1503' to 1527'. Sliding time 0.75 hours. Circulate high viscosity sweep. Ream and clean tight hole from 1490' to 1527'. Drill ahead from 1527' to casing point at 1575'. Ream and clean tight hole. Back ream out of hole to 1200'. Inspect threads on 4" drill pipe. Find damaged threads in box and pin area of new pipe from U.S. factory. The center connections had no damage. RIH to bottom without encountering any fill. Circulate and condition mud. Pump sweep. POOH wet. Lay down instrument, motor, and bit. "Shirt tail" on bit is extremely worn, all the way down to the lubricator cap snap ring grooves. Lubricator cap snap rings and covers left in hole. Hold PJSM. Change bales and elevators. Rig up to run 13 3/8" casing. Run 13 3/8" O.D., 681b, L-80 BTC casing. 811012000: Continue running 13 3/8" casing to tight hole at 1550'. Break circulation. Run in and set casing in slip bowl on rig floor. Shoe depth at 1568'. Work pipe to 1568'. Rig down casing equipment. Rig up to run Stab-In assembly. RIH with Stab-In assembly. Pick up 5 joints of 4" drill pipe. Rig up cementing head and surface lines. Stab into float collar. Circulate and condition mud. Hold PJSM. Test lines at 3000psi. Cement with 600 sacks class G cement (with 34% D-124, + 0.65% D-65, +0.1% D-46, + 0.3% D-79) mixed at 12.0ppg with a yield of 2.38 cu/ft per sack. Cemented with full returns and circulated 100 sacks to surface. CIP at 19:00 hours. Bump dart and check flow back. Unsting from Stab-In float collar. Floats holding. Remove plug dropping head. Pull 2 stands. Wash up surface equipment. Lay down plug dropping head. Adjust Top Drive torque tube. Lay down 5 joints of 4" drill pipe. Work hardened saver sub. Make up into stump 7 times. Make saver sub up on Top Drive. Check Top Drive for alignment. 811112000: Make up Top Drive to drill string and back out. (Saver sub had been damaged). POOH with 4" drill pipe. Rig up to remove slip bowl. Change elevators. Pick up casing and land. Nipple down diverter system. Pick up diverter. Make rough cut on casing. Lay down casing and continue to nipple down. Work on casing head. Cut off 20' flange and set out. Crib up cellar for welder platform. Make final cut on 20" casing.' Center up 13 318" casing in 20" conductor and stabilize. Set in 13 3~8" head. Level and weld out. Let head cool. Test to 1500psi with nitrogen. Tested OK. Install double studded adapter and spacer spool. 811212000: Nipple up BOPs and related equipment. Pick up tools and pick up around rig and location. Function test BOPs. Rig up to test BOPE. Set test plug. Rig up test manifold to Top Drive. Test BOPs and related equipment at 250psi Iow and 3000psi high. Pull test plug and install wear ring. Change saver sub on Top Drive. Work with TESCO on pipe galling problem. RIH with damaged 4" drill pipe. 811312000: POOH and lay down damaged 4" drill pipe. Lay down 17 ~" drilling tools. Unload drill pipe from truck and bring new BHA to rig floor. Pick up new BHA for 12 ¼" hole section. Make up BHA #3. Load MWD and orient. Repair broken elevator hose and guard. RIH with BHA #3. Place corrosion ring in top HWDP. Pick up drill pipe and stand back in mast for next hole section. RIH with stands from derrick to 1466'. Pick up drill pipe and stand back in mast. Trip in hole and tag cement at 1518'. Circulate and condition mud. Pressure test casing to 1500psi. Drill cement and float collar at 1523' Wash to 1538'. Tag cement. Drill cement and float shoe at 1568'. Wash from 1568' io bottom at 1575'. Drill new hole from 1575' to 1594'. Circulate bottoms up. Perform Leak Off Test with 9.2ppg mud weight. 8/'14/2000: Clean pill pit. Flush circulating line. Mix Safe-Clean spacer. Pump spacer and displace well with FLO-PRO mud. Drill and slide from 1594' to 1892'. Repair hydraulic hose on carrier. Check out Cotta Box. Drill and slide from 1892' to 2555'. Circulate bottoms up. Fill trip tank and check for flow. POOH to 13 318" casing shoe at 1568'. Monitor well. RIH to bottom. Tag up on 6' of fill. Wash to bottom. Drill and slide ahead from 2555' to 2946'. 811512000: Generator goes down during drilling. Attempt "quick fix" of generator without success. POOH 5 stands and work pipe while working on generator. Complete fix of generator and RIH. Wash and ream from 2878' to 2946'. Tag fill at 2935'. Drill and slide ahead 'from 2946' to 3735'. Circulate bottoms up until clean. POOH to 2475'. Service rig and Top Drive. Monitor well. RIH. Tag and work through bri.dge at 3652'. Wash and ream from 3699' to 3735'. Ream through 12' fill. Drill and slide ahead from 3735' to 4028'. Shear nail on pop off valve. 811612000: Work on mud pump. Inspect filters on hydraulics. Drill and slide ahead from 4028' to 4293'. Penetration rate slowed from 60'/hr to 25'/hr. Motor stalling easily on bottom with only light bit weight. Heavy drag (60K-70K) picking up off bottom. Back ream out of hole through the Sterling (Sands) Formation to 4169' with 40K 60K drag. Repair hydraulic hose on rotary table drive motor. Continue back ream to 3771' with 40K-drag decreasing to 10K to 15K. Circulate bottoms up. Resume trip. Tight hole at 3706' (60K-70K drag). Continue backreaming to 3326'. Drag decreases to 10K. Finish trip out of hole. Recorded only light (10K-8K) drag pulling to casing. Lay down mud motor. Motor and stabilizers are OK on visual inspection. Pick up new motor. Install MWD. Surface test MWD. 811712000- RIH with New Bit #3 to 1530'. Slip and cut drill line. Service rig. Continue RIH. Work through tight hole at 3737' with 40K-50K. Tag fill at 4253'. Wash to bottom. Rotate and slide from 4293' to 4859'. Average penetration rate is 65'-130'ft/hr, but occasional 20'-30' sections of slower 25-33ft/hr drilling with frequent motor stalls. Pumped 2 high viscosity sweeps with no marked increase in cuttings returns, but considerable improvement in torque and drag reaction Circulate another high viscosity sweep. . 8/18/2000: Do 10 stand wiper trip to 4220'. Experience 50K-80K drag from 4764' to 4675' and 10K-25K drag from 4675' to 4220'. Have no problems trip in ba bottom. Rotate drill and slide drill from 4859 ..... , , P g ck to 10-20'/hr, with reactive torque and erratic too'[-° b442 .. 162 total slide drilling at avera, e occasional high toroue and ~r .......... I faces. Average 40'/hr ro* .... -,--',,, ...g ,, ~u~n[ motor stalls at Iow bit ,,,-,~--~,, .... ,.a,y u[~lllng w~n ,,~,~,,L~. r~gn viscosity sweeps very successful in improving hole conditions. Backreaming all connections. Consistent 10K-30K drag in hole. 8/1912000. Rotate and slide drill from 5442' to intermediate casing point at 5810'. Total 10' of slide drilling at 10'/hr. Circulate bottoms up. Level derrick. Do wiper trip from 5810' to 3310'. Backream from 5810' to 4350' with 30K-100K drag and frequent high torque. Pull without backreaming and only 10K-20K drag from 4350' to 3300'.Trip in hole with no problems. Tag on 40' of fill. 8/2012000: Wash to bottom. Circulate hole clean. Condition mud. POOH. Lay down directional tools. Install 9 5/8" casing rams in BOP's. Pull wear bushing. Install test plug. Cavity test BOP's at 250psi Iow, 3000psi high. Rig up to run casing. Run 9 5/8" casing. 812112000: Continue running 9 5810'. 5/8" casing (114 joints total). Wash 50' to bott Circulate with casing and prepare to cement. H _ . _ om at old PJSM. Cement 9 5/8" casing with a lead slurry of 40bbls Mudpush XL Preflush, and a tail slurry of 570 sacks Class G cement (+ 34% D-124 + 0.65% D-65 + 0.1% D-46) at 12.0ppg and a yield of 2.38 cubic fi/sack. Displace with 438 bbls of 9.2 mud. Observed full returns and did not bump plug. Final displacement pressure is 645psi. Shut down. Release pressure. Floats holding. Wait on cement. Nipple down BOP's. Set slips on casing with 200K hanging weight. Set out spacer spool and DSA. Nipple up 13 3/8" 3Mx11"5M tubing spool and test to 2100psi. Nipple down and set out single ram. Nipple up BOP's. 8/22/2000: Continue to nipple up BOP's. Modify bell nipple and trip tank lines. (Note two ram configuration approved by AOGCC and BLM. Received issue of non- co. mpliance from BLM for requirement of kill line check valve and/or 1" ball valve on annular hydraulic closing line). Finish nippling up BOP's. Test BOP's. (Annulars: 250psi Iow / 2500psi high. Pipe rams, Blind rams, Choke and Kill line valves, Choke manifold, upper and lower Kelly cock valves, all Floor valves: 250psi Iow / 5000psi high). Install wear bushing. Hook up flow line and trip tank. Align BOP stack and tighten turnbuckles. Dress floor. 8/2312000: Pick up steerable BHA and MWD. Surface test same. RIH with HWDP. Strap and pick up 70 joints 4" drill pipe. RIH to 3332'. Test casing to 1500psi. Service rig and Top Drive. Continue RIH. Tag float collar at 5732'. Apparently no cement on top of float collar. Appeared to be drilling light scab cement in shoe joints with 0-5K weight. Drill cement and float equipment. Drill 20' of new formation to 5830'. Circulate bottoms up. Rig up Dowell and perform Leak Off test. Pump into formation at 1145psi/ 13.4EMW. Rotary drill and slide drill from 5830' to 6116'. Average ROP is 50-60ft/hr with light to moderate torque. Drag is 50K-60K while backreaming first time on connections, and 10K-15K on second pass. 8~24~2000: Rotary drill and slide drill and survey from 6116' to 6956'. Average ROP sustained at 50-60 fi/hr. Note that there is no sliding after 6293'. 8~25~2000: Continue to rotary drill and survey from 6956' to 7587'. Average ROP sustained at 50-60 fi/hr. Frequent motor and drill string stalls. 20K-70K drag and 10M- 15M torque while backreaming over short (2'-8') intervals. One backream pass is usually all that is required to clean up after stalling. Connection times, with one or two backreaming and reaming passes included, are 20-40 minutes. At 7587', despite progressively lighter attempted bit weights, there is significantly increased torque and constant motor stalling. CBU. POOH. Pull from 7587' to 7265' with 30K to 90K drag. Backream from 7265' to 7040'. 8/26/2000. Pull from 7040' to 6310' with 25K to 80K drag. Backream from 6310' to 5845' with moderate to heavy torque. During backreaming there is frequent stalling despite generally light drillstring weights. Finish POOH. Change out bit. Surface test MWD. RIH with Bit #6 to 5796'. Service rig and Top Drive. Slip and cut drill line. Continue RIH. Take 50K-70K drag while running in after 7295'. RIH to 7485'. Wash from 7485' to 7587' without fill. Drill from 7587' to 7694'. 812712000: Continue drilling from 7694' to 7980'. Hole conditions unchanged. 25K- 70K drag while working pipe. Stalling motor off bottom. Stopped backreaming at 7705' with no problems. Drilled sand from 7940' to 7980' and had a gas peak of 1183 units. Background gas fell to 35 units. CBU. Continue circulating while waiting on orders to drill deeper. Drill from 7980' to 8110' (T.D.). CBU. Background gas is 35 units. POOH to 5800'. Alternately pull and backream from 8110' to 7450' with 40K-100K drag. Pull from 7450' to 5800' with 15K-40K drag. Replace grabber dies on Top Drive. Service rig. 812812000: RIH to 8110' with 15K-40K drag. No fill. Gas was bubbling in the header boxes while running in, and gas units increased from 35 to 100. Circulate at 8110'. Had 2500 units of gas at 2000 strokes, 3500 units at 3300 strokes, Mud overflowing BOP stack. Close annular preventer and circulate through choke manifold for 1 ~ hours at a reduced pump rate. Maximum gas is. 3545 units. Circulate and build mud weight to 10.6ppg. Open annular and increase pump rate. Circulate around and kill high .gas. Gas reduced to 65 units. Shut down pumps for 30 minutes and observe well. CBU. Gas decreased from 65 units to 25 units. Drop gyroscopic survey and pump to bottom. POOH. Pull from 8110' to 5810' with 25K-60K overpull. Finish POOH. Lay down mud motor and MWD. Retrieve Gyro. Rig up Schlumberger for wireline logs. Begin logging. First run is CMR-CNL-PEX-AIT. Log from wireline TD of 8106'. 8/29/2000: Finish first logging run. Do second logging run with DSI-GPIT-NGT. Finish second logging run. Start first of 3 passes with RFT tool. Finish third logging run. 813012000: Do fourth and fifth logging runs with RFT tool. Sample at numerous points. Finish wireline logging and rig down Schlumberger. Pick up and make up BHA. RIH with 4" drill pipe to 9 5/8" shoe at 5810'. Circulate at shoe. Continue RIH to 8105'. Tag fill. Wash down to 8110'. Circulate rotate and reciprocate pipe. Had 440 units of Trip Gas. Condition Mud. Spot seven barrel 16.0ppg pill on bottom. POOH to 5750'. Service rig. POOH laying down 4" drill pipe. 813112000: Continue POOH laying down 4" drill pipe. RIH with 41 stands 4" drill pipe from derrick to lay down. POOH laying down drill pipe. Lay down HWDP and BHA. Clear floor of handling tools. Pull wear ring. Install and energize test plug. Change pipe rams to dual 3 ~" rams. Install second valve on tubing head. Rig up to test annulus valve on tubing head and flange. Test dual rams. Pull VR plug. Pull test plug. Hold PJSM for dual string rig up. Rig up to run dual strings. Change to long links. Rig up spider and elevators for 3 ~" and 2 7~8" strings. Build safety joints for well control. 9/01/2000: Hold PJSM for making up float equipment. Make up dual string float equipment. Check floats. RIH with dual strings. 9~02~2000: Continue RIH with dual strings to shoe. Switch over from back side well control to dual string circulating head. Fill pipe and circulate bottoms up at shoe. Switch over from circulating head to backside well control. Continue RIH with dual strings. 910312000: Finish first logging run. Do second logging run with DSI-GPIT-NGT. Finish second logging run. Start first of 3 passes with RFT tool. Finish third logging run. 9~04~2000: Do fourth and fifth logging runs with RFT tool. Sample at numerous points. Finish wireline logging and rig down Schlumberger. Pick up and make up BHA. RIH with 4" drill pipe to 9 5/8" shoe at 5810'. Circulate at shoe. Continue RIH to 8105'. Tag fill. Wash down to 8110'. Circulate rotate and reciprocate pipe. Had 440 units of Trip Gas. Condition Mud. Spot seven barrel 16.0ppg pill on bottom. POOH to 5750' Service rig. POOH laying down 4" drill pipe. ' 910'512000: Continue POOH laying down 4" drill pipe. RIH with 41 stands 4" drill pipe from derrick to lay down. POOH laying down drill pipe. Lay down HWDP and BHA. Clear floor of handling tools.- Pull wear ring. Install and energize test plug. Change pipe rams to dual 3 ~" rams. Install second valve on tubing head. Rig up to test annulus valve on tubing head and flange. Test dual rams. Pull VR plug. Pull test plug. Hold PJSM for dual string rig up. Rig up to run dual strings. Change to long links. Rig up spider and elevators for 3 ~" and 2 7/8" strings. Build safety joints for well control. 910612000: Hold PJSM for making up float equipment. Make up dual string float equipment. Check floats. RIH with dual strings. 910712000: Continue RIH with dual strings to shoe. Switch over from back side well control to dual string circulating head. Fill pipe and circulate bottoms up at shoe. Switch over from circulating head to backside well control. Continue RIH with dual strings. 910812000' Do fourth and fifth logging runs with RFT tool. Sample at numerous points. Finish wireline logging and rig down Schlumberger. Pick up and make up BHA. RIH with 4" drill pipe to 9 5/8" shoe at 5810'. Circulate at shoe. Continue RIH to 8105'. Tag fill. Wash down to 8110'. Circulate rotate and reciprocate pipe. Had 440 units of Trip Gas. Condition Mud. Spot seven barrel 16.0ppg pill on bottom. POOH to 5750'. Service rig. POOH laying down 4" drill pipe. 910912000' Continue POOH laying down 4" drill pipe. RIH with 41 stands 4" drill pipe from derrick to lay down..POOH laying down drill pipe. Lay down HWDP and BHA. Clear floor of handling tools. Pull wear ring. Install and energize test plug. Change pipe rams to dual 3 ~" rams. Install second valve on tubing head. Rig up to test annulus valve on tubing head and flange. Test dual rams. Pull VR plug. Pull test plug. Hold PJSM for dual string rig up. Rig up to run dual strings. Change to long links. Rig up spider and elevators for 3 ~" and 2 7~8" strings. Build safety joints for well control. 911012000. Hold PJSM for making up float equipment. Make up dual string float equipment. Check floats. RIH with dual strings. 9/1112000: Continue RIH with dual strings to shoe. Switch over from back side well control to dual string circulating head. Fill pipe and circulate bottoms up at shoe. Switch over from circulating head to backside well control. Continue RIH with dual strings. 911212000. Do fourth and fifth logging runs with RFT tool. Sample at numerous points. Finish wireline logging and rig down Schlumberger. Pick up and make up BHA. RIH with 4" drill pipe to 9 5~8" shoe at 5810'. Circulate at shoe. Continue RIH to 8105'. Tag fill. Wash down to 8110'. Circulate rotate and reciprocate pipe. Had 440 units of Trip Gas.' Condition Mud. Spot seven barrel 16.0ppg pill on bottom. POOH to 5750'. Service rig. POOH laying down 4" drill pipe. 911312000: Continue POOH laying down 4" drill pipe. RIH with 41 stands 4" drill pipe from derrick to lay down. POOH laying down drill pipe. Lay down HWDP and BHA. Clear floor of handling tools. Pull wear ring. Install and energize test plug. Change pipe rams to dual 3 ~" rams. Install secOnd valve on tubing head. Rig up to test annulus valve on tubing head and flange. Test dual rams. Pull VR plug. Pull test plug. Hold PJSM for dual string rig up. Rig up to run dual strings. Change to long links. Rig up spider and elevators for 3 ~" and 2 718" strings. Build safety joints for well control. 911412000: Hold PJSM for making up float equipment. Make up dual string float equipment. Check floats. RIH with dual strings. 911512000: Continue RIH with dual strings to shoe. Switch over from back side well control to dual string circulating head. Fill pipe and circulate bottoms up at shoe. Switch over from circulating head to backside well control. Continue RIH with dual strings. 911612000: Do fourth and fifth logging runs with RFT tool. Sample at numerous points. Finish wireline logging and rig down Schlumberger. Pick up and make up BHA. RIH with 4" drill pipe to 9 5~8" shoe at 5810'. Circulate at shoe. Continue RIH to 8105'. Tag fill. Wash down to 8110'. Circulate rotate and reciprocate pipe. Had 440 units of Trip Gas. Condition Mud. Spot seven barrel 16.0ppg pill on bottom. POOH to 5750'. Service rig. POOH laying down 4" drill pipe. 911712000: Continue POOH laying down 4" drill pipe. RIH with 41 stands 4" drill pipe from derrick to lay down. POOH laying down drill pipe. Lay down HWDP and BHA. Clear floor of handling tools. Pull wear ring. Install and energize test plug. Change pipe rams to dual 3 W' rams. Install second valve on tubing head. Rig up to test annulus valve on tubing head and flange. Test dual rams. Pull VR plug. Pull test plug. Hold PJSM for dual string rig up. Rig up to run dual strings. Change to long links. Rig up spider and elevators for 3 ~" and 2 7/8" strings. Build safety joints for well control. 9/1812000: Hold PJSM for making up float equipment. Make up dual string float equipment. Check floats. RIH with dual strings. 9/19/2000: Continue RIH with dual strings to shoe. Switch over from back side well control to dual string circulating head. Fill pipe and circulate bottoms up at shoe. Switch over from circulating head to backside well control. Continue RIH with dual strings. 9/2012000: Do fourth and fifth logging runs with RFT tool. Sample at numerous points. Finish wireline logging and rig down Schlumberger. Pick up and make up BHA. RIH with 4" drill pipe to 9 5/8." shoe at 5810'. Circulate at shoe. Continue RIH to 8105'. Tag fill. Wash down to 8110'. Circulate rotate and reciprocate pipe. Had 440 units of Trip Gas. Condition Mud. Spot seven barrel 16.0ppg pill on bottom. POOH to 5750'. Service rig. POOH laying down 4" drill pipe. 9/21/2000: Continue POOH laying down 4" drill pipe. RIH with 41 stands 4" drill pipe from derrick to lay down. POOH,laying down drill pipe. Lay down HWDP and BHA. Clear floor of handling tools. Pull wear ring. Install and energize test plug. Change pipe rams to dual 3 ¼" rams. Install second valve on tubing head. Rig up to test annulus valve on tubing head and flange. Test dual rams. Pull VR plug. Pull test plug. Hold PJSM for dual string rig up. Rig up to run dual strings. Change to long links. Rig up spider and elevators for 3 W' and 2 7~8" strings. Build safety joints for well control. 912212000: Hold PJSM for making up float equipment. equipment. Check floats. RIH with dual strings. Make up dual string float 912312000: Continue RIH with dual strings to shoe. Switch over from back side well control to dual string circulating head. Fill pipe and circulate bottoms up at shoe. Switch over from circulating head to backside well control. Continue RIH with dual strings. · i , ' ....:' ' '; . T ~1 ~ t~ ~o ~ u::i 1~i ~> ~ ~ ~: ~ o 08~ 24.0 24.0 0~07 25 1.0 1.0 0.5 19.0 24.0, , 0~8 20.0 1.0 3.0 24.o 0~9 8.5 14.5 1.0 24.0 0~10 o.s 5.0 2.0 1.0 1.0 ~s 2~0 . . 08/11 8.5 35 2.5 1.5 8.0 ~.0 ~12 ~5 2.~ 9.0 S.5 2.~ 24.0 i ou13 2.5 ~3.5 8.0 24.0 0~14 1.5 3.~ 6.0 13.0 i 08/15 0.5 0.5 1.5 3.0 2.0 6.~ 1.0 24.0 , ou~s ~7.0 3.s 2.5 1.0 ~0 0~7 16.5 o.s ~.~ 3.s o.s 1.5 .I " ~.0 08/18 10.5 2.5 ~2.s 1.5 1~ : '~ - o~ 5.0 2~0 ., ou19 14.o ~.5 o.~ 1.o o.~ o.s 2.o ~.o ,., , . . ,, . . O~o =o ~.o ., ..~ ... 0~1 15.5 2.0 5.5 1.0 '~ 24.0 0~2 7.0 0.5 2.0 ... .~.0 6.0 2.5 24.0 0~3 2.0 .~.5 3~0 o.s 7.s 5.~24.0 ~4 12.0 19.0 3.024.0 .... ~08~5 8.~' 8.0 1.0 O.S 4.5 1.o ~.0 2~.0 , ... ., ,0~6 =0 . I 1.0 24.~ o~7 ~.~ 2.0 ~.s' ' .... 2~.o i ' i ~8 3.0 13.0 ~.~ 0.~ 1.0 l' 3.0 24.0 .... o8~o ~s.s 3.o '4.s ~.o 24.0 '°%o ..o ~.o ..... 1~0 ~.5 0.5 24:0 o8~1 ' " 24.0 i ., . . 09~11 s.s 3.~ 0.5 12.0 ' 2.o 00~2i , ~0.0 ,- .. s~ ~.s 2.5 2~ ~.~ 09~3 19~' 4.5 ~.0 . , . 09~4 3.5 ,, ,,a.O 4.0 4.5 4.o24.0 . , , , , .... 0.0 ' ~ ' _ 0.0 0.0 , ,~ o.o 0.0 0.0 , o.o- . , 0.0 0.0 , ~ ', o.o , . , 'TOTAL 217.5 9~5 19.0 ~ 7.5 7.0 ~ ~0 ~5 41~ &5 ~9.5 12~ ~ 7~5 ~ 17.5 31.0 ~.0 ~0 0.0 ~0 ~0 ~ ~.0 . ~ ~1~ 1~2~ ~% 5,~ 1,~% 0,97~ 3,12% 0,26% ~ ~7~ ~ 9,~ 1,74~ ~ 1~% 3,~ 2.~ 4.~ ~14% 0,26% 0.~ . I i , ,, i , . : MUD. REPOR RECO .,..,~.,,...~,~:,,..~.,...,.,.,,, ~.,...:.~..~.:.,~.,,,,...,., .,~..,.;,,...,..::.;,,~..,..,,.,,, ,..:[:Jj ~I..(.,'.3~',:S'.~,. ,' ..... ..,...,. I...,,,...:.,...,....,, ..,.:., J 'MA RA..fHO'N, 01 i~..c ~M '.Fi A'Ni.".i.., i' ::'": ii..:?i.?.''': !.'":. :?!i ".'i::i?ili'!:',i';:,.'ii.?'j~'./~'~?a.~'~:.,:::~..:.il ','i."':'?:..,;:i;! !:'.ii '¢i' i!??:';'".:' .i!'. ': !'"!i:.:. 'ii'",' :i:'?.;:!:: ;::.'",~': !"? ;. !'.?:?',,i .'i?~':~'h:~'i' :~ 'A~.' ': .i~"!':t'E Df" ":" ' " II ' ' '" " ''' "' ' ''"'~'" '"""~ .... "" "J'""" g ' -''k'"~ '':''j' :"' "11''2'''''~''' 4,',"".:4: "~"''"1;' "'"'"l" ;""'"1 "'~'"';"'1%'1 ''''~ ...... " "' ";Ih '"l'""l'"'i"" "'" '"'" 'i: '~'l' '"' ":' ' ":'1'" ' .... LKENAI PENNINSULA, AK UGUST 06r 2000 to AUGUST 25~ 2000 GLACIER DRILLING RIG #1 APl Num, ber': 50-133-20491'-00 ,,, . .... Depths: 42' to 912,1~ , , DATE DEPTH MW VIS PV YP GELS FL- ' FC SOL -OIL 'SD 'MBT pH Alk CI- Ca+ MD I TVD !' 8/5/00 [ 217/217 I 8.90 .1 158 / 9 J 62 1 45/50/501 13.6 -I 3' i 4.0 - 0 I 2.00 ' 17.5 I 9.0 0.20 I 900 I 40 -~'~"'~f~"-~"9~ 85 ~ ~~ 37 26144146 9.8 , 3 '' 6.0 i~.00' 20.0 8.5 : TR 40~1. 60 - 5~4/~'~" 1~'~5g~'5~ ~--~~']--- 1--~[~'- 3/811~ ' 22.0'~ ' 3~ 7.~!- 0~~ '"~/0~-~5/--~4~- .... "~"~-~/~ 1~'~-~ ?~--~~ ...~.~ ~ 7.0~~~ 2.00 '-' 17.~~ 8.0~~ '-sE/bT ~72~ ~ 8.Fo I 45 ~-~ , 25 ~3/ls=~J~, ~ 4.0 ~~~.5. · ~..]-~~o~ ..... ~.--j .... ~.?~.-~j~~ ~~ ~.~ ~~~~~-~ ~D~C~~5' -~7~0 ~ 53 1~~~~~ 0.25 I 1-3.8 9.0 0.20 : 32000 ~GO 5/15/00 [ 5810/5329 ~ 9.40 I 46 12 I 1~ 3/10/14 6.5 I 2 8.0 [ 0 J TR ~ 8.5 , 0.t0 43000 I 40 "~fi'~q .... ~~ .... I'"'D~O-']~"~"-J"~'~F~~~~_~ BIT RECORD MARATHON KTu '32-7 KENAI GAS FIELD GLACIER DRILLING RIG #1 i'! '"lA'tlg~t:O$i' 2000 tO August 25, 2000 · . APl Number $0-~33-2049'1-00 Depths: 22' to 9121' , "J 1 117.51 2 i12.25]STC MO5SODCL T LK6167 16-16-20-12 ..... -+ ....... -4. ......................... 3 i 8.5 ISTC FGSC i LR9549 ] 16-18-20-12 4 j 8.5 fSTC M15TPS ! LW1330 i 18-18-16 5 i 8.5 iSTC M15TPS ~ LW1306 i 18-18-18 6 .8.5j ~ t -' ...... '~- , 3" 7"'T ~.o ] ' '-Fie HRS ROp { 'WOa } PJ~M . j . PP _ eRADE... DEPTH {{ DEPTH { ..... . ' '' ' ! 'i .... - IN { OUT {. { Avg ' Hi-L0-Avg ' I-O-D-L-B-G-OT-R lO8 { 15o4 { -{ ; " -~ "' ' ; · ! ~ ' i " .... -+~ ' .' 'i- '. =-: ~ .r-, 4293 i..5810' ! !517! 38..78 {-42.5.: .- N/^'~-~"~- ~-~T-A-E-1/e-NO-TD - { } {-. i'' -. i- ' { - '- .-{. -' ~ . _ ~; ~. . . . ~.~ { .. { .-.._.~ .. . : { _ MAI~THO~ OIL COMPANY KTU 3J-? KE~Ai ~$ 'Fill~ ......... l~l ~~1 l , 1 t ~.~ ~.~_ 18.~ ~ ~.~ 1 ~.~ ~.~ 0.~ 0.28 0.37 0.37 2 ~.~ 0.~ ~.~ ~ 78.~ ~.~ ~.12 3.~3 0.~ 0.20 0.15 3 ~.~ 0.97 318.~ ~.~ 4~.97 ~.~ 4.~ 0.10 0.77 0,10 4 ~.~ 1 .~ 270.~ 110.~ ~.~ ~.91 5.~-- - -2.~ 1.07 0.~ 5 ~.~ 2.~ 2~.~ 1~.~ ~.~ -1.~ 4.~ -5.~ 1.~ 0.~ 6 7~7.~ 3.87 241.~ 91.~ ~.74 1.~ 2.~ -10.19 1.~ ~ 1 .~ 7 ~5.~ 4.~ 241.~ ~.~ 824.~ 6.~ ~.~ -15.~ 0.20 0.19 8 ~ 7.~ 2.~ 242.~ ~.~ 916.~ 10.74 -3.28 -20.~ -1.24 -1~24 9 1013.~ 2.55 245.70 ~.~ 1012.25 14.13 ~.28 -24.~ 0.~ ~.~ 10 11~.~ 1.32 __ 2~.~ 125.~ 1137.18 16.77 ~.52 -28.51 1.12 ~.~ 11 1322.~ 0.~ ~.~ 1~.~ 1321.15 16.74 ~.~ ~1.24 0.70 ~.24 12 1~2.~ 1 .~ ~2.~ 1~.~ 1451.13 15.~ ~.42 ~2.23 0.13 0.13 13 1528.~ .... 1.10 ~.20 76.~ 1527.12 14.37 -2.15 -32.~ 0.07 0.07 14 1~.~ 1.10 2~.70 52.~ 15~.11 14.32 -1.81 ~.~ 2.~ 0.~ 15 1~:~ 3.~ 215.~ ~.~ 1~9.07 16.15 ~.~1 ~.~ 5.97 5.18 16 1~.~ 5.~ 2~.~ 1~.~ 1~.~ 24.~ -10.~ ~.~ 1.~ 1 .~ 17 1 ~.~ 7 .~ 2~ .~ 1 ~.~ 1 ~.~ ~.~ -20.77 ~.~ 2 .~ 2.02 18 18~.~ 9.~ 2~.10 ~.~ 1~.37 ~.~ -29.16 ~.32 2.31 2.22 19 1~.~ 11.07 2~.~ 82.~ 1976.11 ~.~ ~2,~ ~.~ 2.~ .... 2.~ ~ 2~.~ 13.~ 1~.20 85.~ 2~.16 77.~ -~.~ ~.32 2.~ 2.~ 21 21~.~ 15.~ 1~.~ ~.~ 21~.67 97.~ -78.~ ~.~ 2.21 .2.19 22 2~.~ 19.07 197.~ 157.~ ~.~ 143.~ -122.24 ~.21 2.~ 2.~ 23 2~.~ 21.20 1~.~ ~.~ ~.~ 171 .~ -1~.31 ~9.~ - 2.71 2.57 24 2~.~ ~.~ ~ 2~.~ ~.~ 2~7.~ 201.~ -177.~ ~.~ 2.77 2.76 25 ~525.~ 24.~ 1~.~ 61.~ 2~.~ 226.~ -2~.76 -107.~ 1.7~ 1 .~ 26 2~.~ 27.~ 1~.~ 123.~ 2~.~ 2~.~ -251 .~ -125.97 2.~ 2.~ 27 2771.~ 28.74 1~.~ 123.~ 2712.32 ~.~ -~.~ -1~.14 -- 0.~ 0.~ 28 ~.~ 28.~ 1~.~ 123.~ 2820.~ ~7.51 ~.~ -1~.10 0.19 ~.15 ~17.~ 28.~ 197.~ 123.~ 2~8.~ ~.~ ~8.11 -1~.41 0.~ ~.14 31~.~ 28.~ 197.~ 121 .~ ~.~ 513.29 ~.~ -1~.~ 0.14 --- ~.07 ~31 3262.~ 28.13 197.~ 124.~ 3144.14 571.~ ~28.76 -217.46 0.~4 -0.14 ~ ~ ~5.~ 28.~ 1~.25 123.~ 3252,~ ~ -~.17 -235.87 0.76 0.35 ~ ~2.~ 27.77 1~.20 ~7.~ ~23.~ ~4.~ -721.~ -282,41 0.~ .... -0.26 ~ ~.~ 26.~ 1~.~ 111 .~ ~1 .~ ~1 -7~.~ -2~:~ 0.~ -0.79 ~ ~.~ 26.~. 2~.~ 1~.~ 3~.~ 913.~ ~.~ , ~28.~ 0.27 ~.~ , ~ 4122.~ 27.~ 201.40 t23.~ ~.~ 970.17 ~.~ ~7.~ 1.~ 0,~ 37 ~7.~ 2~.~ 2~.10 2~.~ 4121.71 ,.1~.15 -1013.52 ~.97 0.~ 0.32 ~ ~95,~ ~.13 201.70 128.~ 42~2 1147~1 -1~.~ ~13~ 0.43 .... ~.41 ~ ~7.~ 28.10 202.40 62.~ 42~ 1t76.22 -1~7.07 ~2~:~ 0.53 ~.~ ~ ~.~ 27.~ 202.40 123.~ ~7.~ 12~.~ -11~.42 ~.~ ~.2~ .... ~.20 41 4742.~ 27.~ __ ~01.~ ~.~ ~.41 12~.~ -11~.~ ~-~7~ 0.77 0.15 42 ~.~ 27.16.,, 202 .~ 197.~ ~7.07 1 ~.07 -1261.78 ~1.73 0.52 ~.~ ~ ~ 5112.~ 27.77 2~.~ 1~.~ 47~.57 1~.~ -1~.~ 523.29 0.~ 0.~ ~ 5251 .~ ~.07 2~.~ 1~.~ ~.~ 1~7.81 -1~.~ ~9~3~' 0.52 -0.~ ~ 5332.~ 28.21 .... 2~.70 8t .~ ~75.71 1~ -~427.74 ~.~ 1 ~ 1.41 ~ ~20.~ 27.77 2~.~ ~.~ ~.42 1576.~ -1~.53, ~1.52 1.13 ~.~ 47 5~2.~ 26.~--- 2~.~ 232 .~ 52~.~ ' 1 ~2.82 1 ~3.19 ~23.26 0.47 ~.~ ~ 5721 .~ ~.28 2~.20 ~.~ 5321.43 1713.~ -1~1.35 ~.71 0.78 ~.~ ~ ~.~ 25.~ 2~.~ ~.~ ~.47 17~.12 -1~2.91 ~.76 0.91 ~,~ ~ ~.~ 23.~ 2~.~ 1~.~ ~15.16 1~.42 -1674.~' ~71.87 1.~ -1.37 51 ~.~ 21 .~ 202.~ 123,~ ~28.~ 1~2.01 -1718.~ -~.16 1,57 -1.57 52 6131 .~--- ~"~__ 21.~ 2~.20 ~.~ ~.~ 1676.~ -17~.25 -7~.~ 0.~ ~.~ 53 ~32.~ 20.39 ~.10 101 .~ 5~.~ 1914.~ -1~6.~ -715.02 1.21 ~.~ ~1 .~ 18.~ ,, 201.10 ~.~ ~,~ 1~.11 -1~7.27 -727.28 -- 1 .~ -1.51 , ~.~ 15.~ .... 2~.~ 103.~ ~.41 1978.~ -1~.~ -~.67 3.20 -3.17 ~ ~.~ 14.85, 201.70 ~.~ ~.16 1~.51 1851.22 -7~.~ - 1.31 -t .23 57 ~1.~ 15.21 2~.40 ~.~ 61~.97 2019.~ -18~.57 -7~.10 ---' 0.43 0.~ ~ ~.~ 11.78 201.70 ~,~ ~,~ 2~1.32 -1~.~ -7~.26 3.~ ~.~ -- ~ 67~.~ 11.67 2~1.~ ~.~ ~21.~ 2~t.61 -1912.~ -7~.71 - 0.11 0.~ ~.~ 11.1~ 2~.~ ~.~ ~.~ 2078.57 -1928.41 -7~.72 0.~ ~.~ ' 61 ~.~ 9.~ 2~.~ 101 .~ 6~.87 2~7.~ -1~.78 -7~ .~ 1.22 -1.22 62 7~.~ .__ 8.~ ..... 1~.~ 120.~ ~2..26 2116.~ -1~.29 -7~.51 0,~ ~.87 7174.~ 7.~ 1~.~ 85.~ 67~.~ 2128.76 -1975.78 -~2.47 1.~ -1 .~ ~74.~ 5.~ 203.~ 1~.~ ~.74 21~.~ -1~.26 -7~.~ ~ 2.24 -2.20 ~ 7~7.~ 2.37 201.~ 1~.~ ~.~ 21~.97 -1~.53 ~.01 2.25 -2.25 7510,~ 0.~ ~.~ 1~.~ 7~1.~ 2151.~ -1~.~ ~.~ 2.31 -2.21 7~.~ 0.~ 1~.~ 1M.~ ~5.~ 2151.~ -1~.~ ~0.~ 0.23 0.14 7816.~ 0.~ 1~.~ 122.~ 7~7.~ 2151.97 -1~7.57 ~.49 0.18 0.~ ~.~ 0.~ 1~.~ 129.00 7476.~ 2152.~ -1~.~ ~.~ 0.~ 0.~ 70 ~:~ 0.~ 1~.~ ~.~ 7570.~ 21~.25 -1~.~ ~.~ 0.19 0.10 71 8191.~ 0.97 1~.10 152,~ 7~2.~ 21~.~ -2~.62 ~ ~.75 0.~ ...... 0~ 72 8271 .~ 0.97 1~.10 ~.~ 78~.~ 21~.42 -~.14 -~1 .~ 0.13 0.~ 73 ~.~ 0.70 220.~ 169.~ 7971.~ ,21~.~ ~.31 ~.12 0.26 ~.16 74 ~.~ 0.97 221.10 123.~ ~.33 21~.52 -2~.67 ~ ~ ' 0.22 0.22 75 76 77 78 ~ ~ ..... 81 ~ ....... MARATHON OIL COMPANY KTU 32-7 DAILY WELLSITE REPORT EPOCH REPORT FOR OTIS WATKINS DATE Aug 10, 2000 TIME 24:00 ! 00:00 DEPTH 1535 YESTERDAY 1510 PRESENT OPERATION= PERFORMING LEAK OFF TEST 24 Hour Footage 25 CASING INFORMATION 9 518"~ 1510' DEPTH SURVEY DATA 1452.00' iii BIT INFORMATION NO. SIZE TYPE 2 8.5" STC MF15 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS FC t SOL L . MWD SUMMARY SIN LW1308 · 45 PV 5.0 SD i INCLINATION 1.05 INTERVAL JETS IN OUT FOOTAGE HOURS 18,18,16 1510 25 0.10 i HIGH LOW AVERAGE 423.0 ~ 1519 71.8 ~ 1515 334.1 72 ~ 1523 39 ~l 1511 61.4 6 ~ 1523 0.4 {~ 1531 2.8 1243 ~ 1523 741 ~ 1511 1178.6 _ i i i AZIMUTH VERTICAL DEPTH 332.50 1451.13 i i CONDITION REASON T/B/C PULLED In Hole CURRENT AVG 310.7 fi/hr 54.6 amps 0.9 Klbs RPM 1155 psi i i DEPTH: 1535 / 1534TVD 7 YP 22 FL 8.4 Gels TR OIL 1% MBL 1.875 pH i 11114115 CL- 46000 8.4 Ca+ 240 CCI INTERVAL TO TOOLS i GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL i LITHOLOGY NIA PRESENT LITHOLOGY N/A DALLY ACTIVITY SUMMARY HIGH LOW AVERAGE 21 ~ 1534 12 ~ 1511 18.7 CHROMATOGRAPHY(ppm) 4301 ~ 1534 2402 ~ 1511 3733.3 N/A LITHOLOGYIREMARKS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUNDIAVG 15120 GAS DESCRIPTION i i i i COMPLETE NIPPLE UP AND TESTING OF BOPE. PICK UP AND MAKE UP BHA AND RIH. PICK UP 4" DRILL pIpE. RIH AND TEST CASING. DRILL FLOAT-CEMENT~SHOE. DRILL NEW HOLE FROM 1510' TO 1535'. CBU. PERFORM LEAK OFF TEST. Epoch Personel On Board= 2 Daily Cost 2310 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 REPORT FOR OTIS WATKINS DATE Aug 11, 2000 TIME 24:00 / 00:00 CASING INFORMATION 9 5/8" @ 1510' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 2 8.5" STC MF15 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC 1 SOL MWD SUMMARY INTERVAL TO TOOLS DALLY WELLSITE REPORT DEPTH 4065 YESTERDAY 1535 24 Hour Footage 2530 DEPTH 3262.00 3803.00 4122.00 INCLINATION 28.13 26.89 27.86 S/N LW1308 INTERVAL JETS IN OUT 18,18,16 1510 HIGH 860.2 @ 1738 15.0 128 @ 3718 0 29 @ 2615 1 2006 (~ 4014 1030 DEPTH: 4054 / 3846TVD 39 PV 8 YP 18 7.0 SD TR OIL 0.5% AZIMUTH 197.50 198.90 201.40 FOOTAGE HOURS 2555 12.83 LOW AVERAGE ~l 2351 305.7 @ Sliding 66.2 ~ 2529 14.1 {~ 1563 1474.1 EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 3444.14 3621.66 3905.90 CONDITION T/B/C In Hole REASON PULLED CURRENT AVG 63.3 86.3 24.6 1903 fi/hr amps Klbs RPM psi FL 10.5 Gels 8/11/13 CL- 41000 MBL 5.0 pH 8.4 Ca+ 520 CCI GAS SUMMARY(units) HIGH LOW DITCH GAS 266 {~ 3715 6 ~ 2685 CUTTING GAS ~ CHROMATOGRAPHY(ppm) METHANE(C-I) 53302 @ 3715 1263 ~ 2685 ETHANE(C-2) 27 {~ 3892 PROPANE(C-3) 8 (~ 3892 BUTANE(C-4) (f~ PENTANE(C-5) @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS LITHOLOGY N/A PRESENT LITHOLOGY N/A AVERAGE 40.5 8116.8 1.5 0.1 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 25 / 85 GAS DESCRIPTION DALLY ACTIVITY 'PERFORM LEAK OFF TEST. DISPLACE SPUD MUD WITH 9.2PPG FLO-PRO MUD. DRILL FROM 1535' TO SUMMARY REPORT DEPTH. Epoch Personel On Board= 2 Daily Cost 2310 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 REPORT FOR OTIS WATKINS DATE Aug 13, 2000 TIME 24:00 / 00:00 CASING INFORMATION 9 518" @ 1510' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 3 8,50" STC MF10 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 VIS FC 2 SOL MWD SUMMARY DALLY WELLSITE REPORT EPOCH DEPTH 5700 YESTERDAY 5377 24 Hour Footage 323 PRESENT OPERATION= PULLING OUT OF HOLE DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5420.00 27.77 202.80 5053.42 5652.00 26,72 203,50 5259.68 5700.00 Preened 26.72 203.50 5302.59 INTERVAL SIN JETS IN OUT FOOTAGE HOURS ' LP8191 18,18,18 5377 5700 323 5.15 HIGH LOW AVERAGE 412.9 ~ 5652 14.9 @ 5377 87.1 352 ~ 5377 65 ~;~ 5378 131.2 33 ~ 5416 11 (!~ 5378 24.5 2421 {~ 5659 1959 ~ 5403 2272.5 ii DEPTH: 5700 / 5302TVD 50 PV 10 YP 36 FL 12.1 Gels 7.0 SD TR OIL 1% MBL 10,0 pH CONDITION REASON T/B/C PULLED In Hole CASING POINT CURRENT AVG 46.6 136.8 25,4 2336 fi/hr amps Nibs RPM psi _ _ 15/24/24 CL- 31000 9.6 Ca+ 120 CCI INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C~5) HYDROCARBON SHOWS INTERVAL LITHOLOGY N/A PRESENT LITHOLOGY N/A DAILY ACTIVITY SUMMARY i · i ii i . i i i HIGH LOW AVERAGE 131 {~ 5577 15 ~ 5400 47.9 TRIP GAS= 135 (~ ~ WIPER GAS= 44 CHROMATOGRAPHY(ppm) SURVEY= 26188 ~ 5577 3029 ~ 5400 9577.7 CONNECTION GASHIGH= 16 ~ 5627 ~ 6.9 AVG= 7 @ 5627 @ 0,3 CURRENT ~ ~ CURRENT BACKGROUND/AVG 10 / 77 i i i i i i i i i NONE LITHOLOGY/REMARKS GAS DESCRIPTION i i i · CONTINUE POOH. MAKE UP NEW BIT. RIH. TIGHT AT 4582' AND 4910'. WASH AND REAM FROM 4976' TO BOTToM.- DRILL FROM 5377' TO 5700'. CBU. DO 16 STAND WIPER TRIP. CBU. POOH E )och Personel On Board= 2 Daily Cost 2310 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 REPORT FOR DARRELL GREEN DATE Aug 16, 2000 TIME 24:00 / 00:00 CASING INFORMATION 7" @ 5690' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 4 6.125" STC XR15DGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS DAILY WELLSITE REPORT EPOCH METHANE(C-1 ) ETHANE(C~2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY DEPTH 5725 YESTERDAY 5700 24 Hour Footage 25 i DEPTH PRESENT OPERATION= CIRCULATING BOTTOMS UP ii i i i INCLINATION ii INTERVAL SIN JETS IN OUT LX5619 14,14,14 5700 HIGH LOW 189.4 ~ 5707 10.8 203 @ 5724 105 17 @ 5720 1 1872 @ 5706 1623 AZIMUTH VERTICAL DEPTH FOOTAGE HOURS 25 1.38 AVERAGE 5718 69.5 5710 143.8 5703 12.0 CONDITION TIB/C In Hole CURRENT AVG 48.0 199.5 10.8 5718 1834.3 1624 REASON PULLED R/hr amps Klbs RPM psi DEPTH: 5725' 1 5315'TVD 39 PV 10 YP 14 FL 7.8 Gels 5/9/14 CL- 39000 8.0 SD TR OIL 2% MBL 7.5 pH 11.0 Ca+ 180 CCI 119 23887 15 2 iii i i i iii i! . i i i iii i i i i HIGH LOW AVERAGE @ 5707 14 @ 5721 50.5 TRIP GAS= (~ ~ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= @ 5707 2929 ~ 5721 10094.0 CONNECTION GAS HIGH= {~ 5707 1 @ 5721 6.3 AVG= ~ 5707 ~ CURRENT @ @ CURRENT BACKGROUND/AVG 14 / 50 ii i i i ii NONE LITHOLOGY/REMARKS ! i i ii GAS DESCRIPTION i i iii . i .i i Ul Major Tuffaceous Claystone, Argillaceous Claystone. Minor Siltstone, Tuffaceous Siltstone, Sandstone, Coal. Trace Tuffaceous Shale, Carbonaceous Shale. TUFFACEOUS CLAYSTONE, ARGILLACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE PICK UP 4" DRILL PIPE AND RIH. PRESSURE TEST CASING. TAG CEMENT AT 5532'. DRILL CEMENT, FLOAT COLLAR, CEMENT, SHOE. DRILL FROM 5700' TO 5725'. CBU. PERFORM LEAK OFF TEST. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 DALLY WELLSITE REPORT EPOCH REPORT FOR DARRELL GREEN DATE Aug 17, 2000 TIME 24:00 / 00:00 DEPTH 6558 YESTERDAY 5725 PRESENT OPERATION= DRILLING AHEAD CASING INFORMATION 7" ~ 5690' SURVEY DATA BIT INFORMATION NO. SIZE 4 6.125" TYPE STC XR15DGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGH'i' ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 2 SOL MWD SUMMARY 44 8.0 24 Hour Footage 833 DEPTH 5721.00 6232.00 6684.00 SIN LX5619 207.0 249 36 INCLINATION AZIMUTH 204.20 202.10 201.90 VERTICAL DEPTH 26.28 20.39 11.98 INTERVAL JETS IN OUT FOOTAGE HOURS 14,14,14 5700 858 17.57 HIGH LOW AVERAGE @ 6506 14.0 @ 5841 64.2 ~ 6382 10 ~ 6207 148.4 ~ 6443 1 @ 6086 15.0 ~ 6220 1624 @ 5725 2139.3 DEPTH: 655816096TVD 5321.43 5790.83 6224.36 CONDITION TIBIC In Hole CURRENT AVG 45.8 228.3 13.8 2381 2242 REASON PULLED PV 9 YP 27 FL 7.0 Gels 11/18/21 CL- 31000 SD TR OIL 2% MBL 7.5 pH 9.5 Ca+ 80 ·. ~ fi/hr amps Klbs RPM psi CCI INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU3-1'ING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL . LITHOLOGY PRESENT LITHOLOGY ii HIGH LOW AVERAGE 352 @ 6513 5 @ 5971 51.3 TRIP GAS= @ ~ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 70408 (~ 6513 1034 (~ 5971 10274.8 CONNECTION GAS HIGH= 115 39 @ 65'15 @ 5.0 AVG= 22 19 ~ 6517 ~ 1.1 CURRENT 25 8 (~ 6348 ~ 0.4 CURRENT BACKGROUND/AVG 11 / 35 · NONE LITHOLOGY/REMARKS GAS DESCRIPTION Major Sand, Tuffaceous Claystone, Argillaceous Claystone. Minor Coal/Carbonaceous Shale, Tuffaceous Siltstone. Trace Sandstone, Siltstone, Volcanic Ash, Calcareous Tuff, Tuffaceous Shale SAND, TUFFACEOUS CLAYSTONE DAtLY ACTIVITY SUMMARY pERFORM LEAK OFF TEST. DRILL FROM 5725' TO REPORT DEPTH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 DAILY WELLSITE REPORT EPOCH REPORT FOR DARRELL GREEN DATE Aug 18, 2000 TIME 24:00 1 00:00 DEPTH 7270 YESTERDAY 6558 24 Hour Footage 712 PRESENT OPERATION= DRILLING CASING INFORMATION 7' (~ 5690' SURVEY DATA BIT INFORMATION SIZE TYPE 4 6.125" STC XR15DGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.8 VIS 46 FC 2 SOL 9,0 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6868.00 11.16 200.00 6404.58 7089.00 8.88 198.50 6622.26 7243.00 6.50 201.70 6774.86 INTERVAL S/N JETS IN OUT LX5619 1'4,14,14 5700 HIGH LOW 262.5 ~ 7157 10.3 281 @ 7264 10 45 @ 7049 1 2695 @ 7136 1847 DEPTH: 7249 / 6781TVD PV 11 YP 34 FL SD TR OIL 1% MBL FOOTAGE 1570 HOURS 32.15 AVERAGE 6927 67.7 6930 164.5 6837 17.7 6840 2379.5 CONDITION REASON TIB/C PULLED In Hole CURRENT AVG 21.1 ftJhr 268.5 amps 11.8 Klbs RPM 2379 psi 6.8 Gels 13/24128 CL- 32000 7.5 pH 9.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE{C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C~5) OCARBON SHOWS INTERVAL HIGH LOW AVERAGE 651 ~ 6791 9 @ 6838 95.1 TRIP GAS= ~ ~ WIPER GASTM 26 CHROMATOGRAPHY(ppm) SURVEY= 133114 ~ 6791 2041 {~l 6838 19296.7 CONNECTION GAS HIGH= 89 @ 6791 ~ 11.8 AVG= 40 ~ 6791 {~ 4.2 CURRENT 34 ~ 6791 (~ 1.8 CURRENT BACKGROUNDIAVG 15 1 85 NONE LITHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone, Coal, Tuffaceous Siltstone. Minor Argillaceous Claystone, Carbonaceous Shale Volcanic Ash, Tuffaceous Shale. Trace Calcareous Tuff, Arenaceous Siltstone. PRESENT LITHOLOGY SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, COAL/CARBONACEOUS SHALE DAILY ACTIVITY SUMMARY DRILL FROM §558' TO 6925'. CBU, WIPER TRIP TO 5690'. DRILL FROM 6925' TO REPORT DEPTH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 REPORT FOR DARRELL GREEN DATE Aug 19, 2000 TIME 24:00 / 00:00 CASING iNFORMATION 7" ~ 5690' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 4 6.125" STC XR15DGPS 5 6.125" STC XR15DGP DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.6 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS 46 12.0 METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY DAILY WELLSITE REPORT EPOCH DEPTH 7541 YESTERDAY 7270 24 Hour Footage 271 PRESENT OPERATION= DRILLING DEPTH INCLINATION AZIMUTH 7274.00 5.36 203.50 7407.00 2.37 201.00 I NTE RVAL S/N JETS IN OUT LX5619 14,14,14 5700 7300 LX5620 14,12,12 7300 HIGH LOW 279.4 @ 7400 11.7 275 {~ 7383 10 46 @ 7472 4 2875 @ 7472 2249 DEPTH: 7530 / 7060TVD PV 12 YP 35 FL SD 0.25 OIL 1% MBL FOOTAGE 1600 241 7366 7475 7328 7385 6.4 HOURS 32.91 6.51 AVERAGE 53.6 153.3 22.2 2627.9 VERTICAL DEPTH 6805.74 6938.43 CONDITION T/B/C 6-3-BT~N3-F-I-CI-HR In Hole CURRENT AVG 16.5 266.6 10.9 2800 Gels 12/27/27 CL- 30000 pH 9.5 Ca+ 80 REASON PULLED HOURS ft/hr amps Klbs RPM psi CCI HIGH LOW 379 @ 7484 7 (~ 7522 CHROMATOGRAPHY(ppm) 75875 ~ 7484 1472 @ 7522 58 @ 7484 @ 33 @ 7484 14 @ 7484 3 @ 7484 i i NONE LITHOLOGY/REMARKS AVERAGE 80.0 16117.7 9.0 3.6 1.1 0.0 TRIP GAS= 40 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 10 / 30 GAS DESCRIPTION Major Sand/Sandstone, Tuffaceous Claystone, Coal. Minor Carbonaceous Shale, Tuffaceous Siltstone, Argillaeous Claystone. Trace Volcanic Ash, Tuffaceous Shale, Conglomeratic Sandstone. SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, COAL iiii ~RiL~ FROM 7270' TO 7300'. OBU. POOH. CHANGE OUT BIT. CHANGE OUT PUMP LINERS. RIH. DRILL FROM 7300' TO REPORT DEPTH, Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 REPORT FOR DARRELL GREEN DATE Aug 20, 2000 TIME 24:00 / 00:00 CASING INFORMATION 7" ~ 5690' SURVEY DATA BIT INFORMATION NO. SIZE 5 6.125" TYPE STC XR15DGP DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.7 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS 45 13.0 DEPTH 7510.00 7694. OO 7816.00 DAILY WELLSITE REPORT DEPTH 8096 YESTERDAY 7541 24 Hour Footage 555 INCLINATION 0.09 0.35 0.35 INTERVAL S/N JETS IN OUT LX5620 14,12,12 7300 HIGH LOW 192.4 ~} 7975 5.8 ~ 305 {~ 8066 142 ~} 22 ~ 7809 4 ~i 2956 ~ 7577 1869 ~} DEPTH: 808717818TVD PV 13 YP 31 FL SD I OIL 196 MBL AZIMUTH 296.30 146.90 184.50 FOOTAGE HOURS 796 27.70 AVERAGE 8096 42.1 7875 279.6 7633 14.8 EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 7041.4O 7225.4O 7347.39 CONDITION TIB/C In Hole CURRENT AVG 5.8 286.9 17.8 REASON PULLED 7634 2655.7 2598 fi/hr amps Klbs RPM psi 7.4 Gels 12/29130 CL- 29000 9.0 pH 9.0 Ca+ 40 CCI GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY HIGH LOW AVERAGE 426 ~ 8001 2 ~ 7548 59.3 TRIP GAS= @ ~ WIPER GAS= 605 CHROMATOGRAPHY(ppm) SURVEY= 85101 ~ 8001 490 ~} 7548 12330.1 CONNECTION GAS HIGH= 57 ~} 6000 ~} 8.1 AVG= 31 @ 8000 {~ 3.8 CURRENT 12 ~} a000 ~ 0.6 CURRENT BACKGROUNDIAVG 3 / 50 NONE LITHOLOGY/REMARKS GAS DESCRIPTION Major Sand/Sandstone, Tuffaceous Siltstone, Volcanic Ash, Tuffaceous Claystone, Coal. Minor Tuffaceous Shale, Carbonaceous Shale, SANDSTONE/8AND, VOLCANIC ASH, COAL, TUFFACEOUS 81LTSTONE DAILY ACTIVITY SUMMARY DRILL FROM 7541' TO REPORT DEPTH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY kTU 32-7 REPORT FOR DARRELL GREEN DATE Aug 21, 2000 TIME 24:00 / 00:00 CASING INFORMATION 7" ~ 5690' DALLY WELLSITE REPORT EPOCH DEPTH 8328 YESTERDAY 8096 24 Hour Footage 232 PRESENT OPERATION= RUNNING IN HOLE SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7945.00 0.35 166.90 7476.39 8271.00 0.97 196.10 7802.36 BIT INFORMATION NO. SIZE TYPE SIN 5 6.125" STC XR15DGP LX5620 6 6.125" STC XR15TDGPS I-Xl158 INTERVAL CONDITION IN OUT FOOTAGE HOURS T/B/C 7300 8328 1028 37.42 6-3-BT-M2-F-1-HR 8328 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 262.4 ~ 8272 5.8 ~ 8096 37.6 19.9 SURFACE TORQUE 316 {~ 8202 223 ~ 8313 296.9 309.1 WEIGHT ON BIT 21 @ 6312 5 @ 8149 16.3 13.8 ROTARY RPM ~ {~ PUMP PRESSURE 2865 ~ 8257 2526 ~ DRILLING MUD REPORT DEPTH: 8328 / 7e60TVD MW 10.8 VIS 46 PV 14 YP 31 FL FC 2 SOL 13.0 SD 0.1 OIL 1% MBL MWD SUMMARY INTERVAL TO TOOLS JETS 14,12,12 14,12,12 8149 2732.7 2770 REASON PULLED HOURS fi/hr amps Klbs RPM psi 7.0 Gels 14/22/35 CL- 31000 9.0 pH 9.5 Ca+ 40 CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 438 ~ 8200 4 ~ 8096 59.3 CUTTING GAS @ ~ TRIP GAS= CHROMATOGRAPHY(ppm) WIPER GAS= 605 SURVEY= METHANE(C-I) 86573 @ 8200 883 @ 8096 11890.7 CONNECTION GAS HIGH= 40 ETHANE(C-2) 74 ~ 8277 ~ 10.3 AVG= 24 PROPANE(C-3) 47 @ 8200 ~ 5.5 CURRENT 24 BUTANE(C.4) 11 ~ 8276 ~ 0.4 CURRENT BACKGROUNDIAVG 10 / 26 PENTANE(C-5) ~ ~ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Claystone, Sand/Sandstone, Tuffaceous Siltstone, Coal. Minor Tuffaceous Shale PRESENT LITHOLOGY SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE, COAL, VOLCANIC ASH. DAILY ACTIVITY DRILL FROM 8096' TO 8099'. DO WIPER TRIP TO 7300'. DRILL FROM 8099' TO 8328'. CBU. POOH. CHANGE OUT SUMMARY BIT AND MUDMOTOR. RIH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 DALLY WELLSITE REPORT EPOCH REPORT FOR DARRELL GREEN DATE Aug 22, 2000 TIME 24:00 / 00:00 DEPTH 8677 YESTERDAY 8328 PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE 6 6.125" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE ~ . DRILLING MUD REPORT MW 11.5 VIS FC 2 SOL i i i iii iii i MWD SUMMARY TYPE STC XR15TDGPS 24 Hour Footage 349 i i i ~ i DEPTH INCLINATION AZIMUTH 8440.00 0.70 220.00 8563.00 0.97 221.10 INTERVAL S/N JETS IN OUT FOOTAGE HOURS LXl158 A4,12,12 8328 349 15.68 HIGH LOW AVERAGE 163.2 {~ 8355 7.8 {~ 8550 33.0 345 @ 8646 176 ~ 8344 293.9 38 @ 8343 7 @ 8575 17.4 2928 {~ 8334 2390 ~) 8499 2773.5 47 PV 15.0 SD DEPTH: 8676 / 8208TVD 14 YP 31 FL 7.2 Gels TR OIL 1% MBL 8.75 pH VERTICAL DEPTH 7971.35 8094.33 ! CONDITION TIB/C In Hole CURRENT AVG 15.7 304.6 19.0 i n 2780 REASON PULLED fi/hr amps Kilos RPM psi 18/37/42 CL- 31000 8.8 Ca+ 40 CCI ii il , i ._ INTERVAL TO TOOLS : GA8 SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL i i HIGH LOW 307 @ 8470 4 ~ 8568 CHROMATOGRAPHY(ppm) 63642 (~ 8470 902 (~ 8526 53 @ 8620 34 @ 8620 12 @ 8620 NONE LITHOLOGY/REMARKS AVERAGE 37.2 7477.4 6.2 2.2 0.2 TRIP GAS= 1885 WIPEr GAS= SURVEY= CONNECTION GAS HIGH= 56 AVG= 24 CURRENT 56 CURRENT BACKGROUND/AVG 9 / 25 GAS DESCRIPTION ' LITHOLOGY Major Sand/Sandstone, Volcanic Ash, Coal, Tuffaceous Siltstone, Tuffaceous Claystone. Minor Carbonaceous Shale. PRESENT LITHOLOGY SAND/SANDSTONE, VOLCANIC ASH, COAL DAILY ACTiviTy SUMMARY CONTINUE RIH. CIRCULATE OUT HI GAS (18'85UNITS). WEIGHT UP MUD TO 11.5PPG. DRILL FROM 8328' TO 86~6'. ii WORK ON MUD PUMP ¢1r2. DRILL tO REPORT DEPTH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 REPORT FOR DARRELL GREEN DATE Aug 23, 2000 DEPTH 8865 TIME 24:00 / 00:00 YESTERDAY 8677 24 Hour Footage 188 CASING INFORMATION 7" @ 5690' DALLY WELLSITE REPORT EPOCH PRESENT OPERATION= CIRCULATE AND CONDITION HOLE. SURVEY DATA BIT INFORMATION NO. SIZE TYPE 6 6.125" STC XR15TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 11,5 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8685.00 1.23 232.70 8216.31 8807.00 1.23 227.30 8338.28 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED LXl158 14,12,12 8328 8865 537 34.09 In Hole HOURS HIGH LOW AVERAGE CURRENT AVG 62.1 ~ 8791 4.4 @ 8844 13.5 5.3 ft/hr 333 @ 8838 138 @ 8743 312.0 316.7 amps 32 ~ 8791 9 ~ 8744 19.9 20.9 Klbs @ @ RPM 2866 (~ 8692 2635 @ 8699 2810.3 2795 psi DEPTH: 8865 / 8396TVD 47 PV 14 YP 31 FL 7.2 Gels 18/37/42 CL- 31000 15.0 SD TR OIL 1% MBL 8.75 pH 8.8 Ca+ 40 CCI GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Epoch Personel On Board= 4 HIGH LOW AVERAGE 232 @ 8802 5 ~ 8860 21.8 ~ ~ TRIP GAS= WIPER GAS= 420 CHROMATOGRAPHY(ppm) SURVEY= 46058 ~ 8802 644 {~ 8679 4559.9 CONNECTION GAS HIGH= 56 50 ~) 8794 ~ 4.9 AVG= 37 32 ~ 8795 ~ 1.9 CURRENT 50 16 ~ 8802 @ 0.3 CURRENT BACKGROUND/AVG 7 / 12 NONE LITHOLOGY/REMARKS GAS DESCRIPTION Major Sand/Sandstone, Volcanic Ash, Tuffaceous Claystone Tuffaceous Siltstone, Coal. Minor Carbonaceous Shale, Tuffaceous Shale. Trace Calcareous Tuff. ' SANDSTONE/SAND, VOLCANIC ASH, TUFFACEOUS SILTSTONE. DRILL FROM 8677' TO 8865'. CBU. DO 21 STAND WIPER TRIP TO 7500'. CBU. CIRCULATE AND CONDITION HOLE. Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 REPORT FOR DARRELL GREEN DATE Au9 25, 2000 TIME 24:00 / 00:00 CASING iNFORMATiON 7"{~ 5690' DALLY WELLSITE REPORT DEPTH 8953 YESTERDAY 8886 24 Hour Footage 67 EPOCH PRESENT OPERATION= DRILLING SURVEY DATA BIT INFORMATION NO. SIZE TYPE 8 6.125" STC XRT DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW . 11.6 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS DEPTH SIN LY3669 45 PV 15.0 SD INCLINATION INTERVAL JETS IN OUT 12,12,14 8895 HIGH LOW 83.3 @ 8907 3.0 351 ~ 8918 318 26 @ 8941 11 @ 2826 @ 8924 1861 DEPTH: 8954 ! 8485TVD 14 YP 22 FL TR OIL 0,5% MBL AZIMUTH FOOTAGE HOURS 58 8.32 AVERAGE 8898 13.4 8922 337.6 8918 20.5 8936 2642.9 VERTICAL DEPTH CONDITION TIB/C In Hole REASON PULLED CURRENT AVG 9.2 332.0 24.2 2686 fi/hr amps Klbs RPM psi 7.0 Gels 15~33~42 CL- 32000 8.75 pH 9.4 Ca+ 40 CCI GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE{C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY 80 17037 22 10 HIGH LOW AVERAGE @ 8908 3 @ 8947 13.7 ~) ~ TRIP GAS= 665 CHROMATOGRAPHY(ppm) WIPER GAS= SURVEY= ~ 8908 634 @ 8947 2892.2 CONNECTION GAS HIGH= 18 @ 8908 ~ 3.2 @ 8908 @ 1.1 AVG= 18 CURRENT 18 ~ ~ CURRENT BACKGROUNDIAVG 3 / 5 NONE LITHOLOGYIREMARKS GAS DESCRIPTION Major Sandstone/Sand, Tuffaceous Siltstone, Volcanic Ash. Minor Tuffaceous Claystone Conglomeratic Sand/Conglomerate, Tuffaceous Shale. Trace Calcareous Tuff, Carbonaceous Shale. ' SANDSTONE/SAND, TUFFACEOUS SILTSTONE DAILY ACTIVITY CORE FROM 8886' TO 8895'. PUMP DRY JOB. POOH. LAY DOWN CORE BIT AND BARREL. (CORE #1: CUT 30', SUMMARY RECOVER 29,8'), MAKE UP AND PICK UP DRILLING ASSEMBLY. RIH. REAM CORED INTERVAL FROM 8865' TO 8895'. CBU. TRIP GAS 665 UNITS. DRILL FROM 8895' TO REPORT DEPTH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA MARATHON OIL COMPANY KTU 32-7 DALLY WELLSITE REPORT EPOCH REPORT FOR DARRELL GREEN DATE Aug 26, 2000 DEPTH 9117 TIME 24:00 / 00:00 YESTERDAY 8953 PRESENT OPERATION= CIRCULATING PRIOR TO WIPER TRIP 24 Hour Footage 164 CASING ~NFORMATION 7" ~ 5690' SURVEY DATA DEPTH BIT INFORMATION NO. SIZE TYPE 8 6.125" STC XRT DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 11.55 VIS 41 FC 2 SOL 16.0 MWD SUMMARY S/N LY3669 PV INTERVAL TO TOOLS ii ! . _ ii GAS SUMMARY(units) DITCH GAS CUTTING GAS 199 METHANE(C-1 ) 39844 ETHANE(C-2) 45 PROPANE(C-3) 29 BUTANE(C-4) 16 PENTANE(C-5) HYDROCARBON SHOWS INTERVAL INCLINATION INTERVAL IN OUT 8895 9117 8987 4.1 9016 305 9068 5 JETS 12,12,14 HIGH 69.6 375 32 2880 @ 8983 1784 DEPTH: 9117 / 8648TVD 13 YP 26 TR OIL 0.5% LOW AZIMUTH ! FOOTAGE 222 8994 9015 8971 9096 VERTICAL DEPTH CONDITION HOURS T/BIC 30.09 In Hole AVERAGE CURRENT AVG 13.6 38.5 339.6 334.5 22.9 25.5 FL MBL 6.6 9.0 2604.8 2661 ' i ii i i i HIGH LOW AVERAGE ~ 8989 2 ~ 9106 28.0 CHROMATOGRAPHY(ppm) 8989 595 @ 9106 5788.1 8969 ~ 8.4 9035 ~ 4.3 8968 ~ 1.3 NONE LITHOLOGY/REMARKS Gels 15/32/36 CL- pH 9,1 Ca+ i REASON PULLED T.D. fi/hr amps Klbs RPM psi 31000 40 CCI TRIP GAS= WIPER GAS= 86 SURVEY= CONNECTION GAS HIGH= 57 · AVG= 24 CURRENT 15 CURRENT BACKGROUND/AVG 3 / 60 GAS DESCRIPTION ii i iii i ii J. ii i i LITHOLOGY Major Sand/Sandstone, Tuffaceous Siltstone, Volcanic Ash, Tuffaceous Claystone. Minor Coal, Carbonaceous Shale, Tuffaceous Shale. Trace Calcareous Tuff, Conglomeratic Sand/Conglomerate. PRESENT UTHOLOGY COAL DAILY ACTIvIT~ ~Ui~IMARY DRILL FROM"8953' TO "91'17' (T.D.). CBU. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA Alaska i' ,on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 23 2000 Alaska Oil & Gas Conservation Commission Attn: Loft Taylor. 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA AIRBORNE EXPRESS The following well logs are enclosed: Marathon Oil Company KTU 32-7 / Keoai Gas Field P~t Reproducibl~ O~..~KTU 32-7- Gamma Ray, Caliper- August 13, 2000 ................................................................. 1'. ................ 1 KTU 32-7 - Repeat Formation Tester, Gamma Ray - August 13, 2000 ..................................... 1 ................. 1 KTU 32-7 - ArraY Induction, Gamma Ray, Caliper, TVD - August 1.3, 2000 ......... : .................. 1 ................. 1 KTU 32-7 - Array Induction, Gamma Ray, Caliper, Platform Express - August 13, 2000 ........ 1 ................. 1 KTU 32-7 'Density, Neutron, Gamma Ray, Caliper, TVD - August 13, 2000 .......................... 1 ................. 1 KTU 32-7 - Density, Neutron, Gamma Ray, Caliper, Platform Express - August 13, 2000 ...... 1 ................. 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman , . Enclosures Airbill No. 1196820155 RECEIVkE · AUG 2 2 2000 Alaska 0ii & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor DATE: Aug. 15, 2000 SUBJECT: FROM: Jeff Jone?~ ~-- Petroleum I~lsp6cror / NON-, CONFIDENTIAL Blowout Preventer Test Glacier dg #1 Marathon KTU-37 200-023 Kenai Gas Field Operator Rep.: Otis Watkins. Contractor Rep.: Mike Leslie Test Type Weekly: X_ Test Pressures Rams: 250/500q MISC. INSPECTIONS: P/F Location Gen.: P Housekeeping: P PTD On Location P Standing Order: P PIF Sign: P Rig cond: P Hazard: P Op. phone: 283-1312 Rig phone: 283-1315. Op. e-mail: Rig e-mail: Annular: 250/2500. Choke: 250/5000 TEST DATA FLOOR VALVES: .Quantity P/F Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P BOP STACK: Quantity Size PIF' Annular Preventer 1 13 5~8" P ,, Pipe Rams 1 4" P , Lower PiPe Rams 1 4" P Blind Rams 1 Blind P Choke Ln. Valves 1 3 118" P HeR Valves 1 3 118" P Kill Line Valves 2 2 1116" P Check Valve 1 2 1116" F MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P ' Meth Gas Detector P P H2S Gas Detector P F ACCU M ULATOR SYSTEM: CHOKE MANIFOLD: Time/Psi. P/F Quantity P/F System Pressure 3000 P ' No. Valves 12 P After Closure 1620 P Man. Chokes 1 P 200 psi Attained :32 P Hyd. Chokes 1 P Full Pressure 2:40 P Blind Covers (All .Stations): P N2 Bottles (avg): 4(~2400 P Test's Details Tuesday, ~ 15~ 2000'.. I traveled to Marathon's Kenal Gas Field to witness a BOPE test on Inlet Drilling rig Glacier #1, drilling gas well KTU 32-7. The rig personnel were ready to test on my arrival and conducted the tests in a safe and profident manner with two failures observed~. Th.e kill line check valve leaked initially, but alter repairs passed the re-test. The.H2S gas detector on the rig floor failed.to activate the audible alarm and was .calibrated, also passing the re-test. The 'drilling rig and it's equipment appeared clean and in excellent condition, and the location was well organized. Summa~: I witnessed a weekly BOPE test on Inlet Drilling's Glacier rig #1, drilling Marathon's gas well KTU 32-7 in the Kenai Gas Field. 42 components testedi-2 failures were observed. Total Test Time: 4 hrs_. Number: 0ffailures: 2_ cc_..~: Pete Ber.qa Marathon drillin,q superviser' ' Attachments: None Vu5bclh7.xls 8/16/00 Re: KTU 32-7 7" Casing (PTD 200-023) {' / Subject: Re: K~ 32-7 7" Casing (P'rD 200-023) Date: Fri, 11 Aug 2000 14:33:05 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Craig E Young <CEYoung@MarathonOil.com> CC: Blair Wondzell <blair_wondzell@admin.state.ak. us> Craig, Thanks for the information and your comparison of the design factors. It would appear that the lighter casing still provides adequate margin beyond the antidpated pressure conditions. I will include this email in the well file. At this time we shouldn't need any further paperwork. Please call if you need anything further. Tom Maunder AOGCC Craig E Young wrote: > Tom, > Per our discussion today, Marathon is running 7" 23 PPF, L-80 casing in place of the approved 7" 26 ppf, L-80 casing due to supply problems. Following is a comparison of design safety factors for both strings: > Approved 7" 26 ppf, L-80 casing > > Burst- 1.71 > Tension - 2. 75 > Collapse- 2.39 > Proposed 7" 23 ppf, L-80 casing > Burst- 1.50 > Tension- 2.57 > Collapse- 1.69 > > The lower section of casing will remain 7" 29 ppf. > If you have any questions, or need any additional information, please give me a call at 564-63'10. > Thanks, > Craig Young > Marathon Oil Company Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 8/11/00 3:23 PM '7 08/1~/00 TI.~ 11:39 FAX. 19075646489 MarathonOll Co · MARATHON OIL COMPANY- GULF COAST REGION CA,~NG AND CEMENTING RECORD : I~1001 Page I of 2 Field: -- _Kermi G .a~._Field. : ,_ Rig:. Glaeie_r O_rillirtg~Ri9#l __ Dal~ Run: L~/14/00 Well.'. . ~ ~- . tCTU, 32-7 _ ~, Cement Colttrac~r: Dowell RKB - MWL: 20 Lease; } ......... _ .... shoe ~ (Tun): 9'~ mm. M,'-__:= . _2o _-, ....... [ "- R~,,°~ ....................... 2~.~ .... o.o~~ ~,~" J , ~ , , .~ . .. ; '- , ._ _ 1 [ .....Ha~era~ ~j~ r' ~e~ LeO 2~ 4,19 2~.50 25,69 · . . i i,, _ i, . , _ _ :, i ii,-~ .. - ., 1 J. ~PupJOint r' B~= .LB0 $~ I0.~ 25.69 35.74 . , - ,._ . . ~ . . ........ . ..... ~ - ..... ,: .! ~ Ftpat ~'t ..... 7. 9~ :p~0 ~ ~.4e ~m.e~ ~e.~ ........ ._ -,- , - 2 -1 Ca~ ~' B~ Pl10 ~ ~.91 5~8.36 -~.~ ~:l.. Ill .I I '" --- ~... '- ' ' __ ~ I ..... ' "LC .~ _ . ' _ ~ I { Ro~ Shoe W' B~ Pl10 2~ ' 1,73 5~.27 ~g0,~ '- ''- "J '' ~ .... ' ~. ~ ......... t ..... _ ..... . ' I ' ' .... ' '" '~ - ' '~ .... . . .t.. ~ ,, _. ,, ._ _ ~ _~_ L_ / '- '1 ' ' ~ ' ' - ' ' ' ' ~ ' - .... ' . ~. : :; ~' e'. _ ~ ' _ -' . ' ~" ' ' .... '~' ' .__ ~ : ' e~'__ "' . ...... -~ - {. '' , ....... ~ , ~. ~ ~. '. ' . ' ........ 5-7. .... T:" .... , , ~ ,11 . il t. ; ,J ,, .................. -._ ' ,,--. · , , , ] , , ,, , _ , r. 1,.~ ,, ,~..__ · , ?" , ,:_.: { ..',. ,?: ~'"" , ,d~.-'*'~'"' . ~,,:~i.,,,':';'~''' :. ,~;' ~:,v;~"; ~EMF.~;~,CH~; .' ,;i;:,: ; ,,,.,:i;.:.:::' .... if ?;i ...... , .: :i;~i .... , , ,",."' ' . ;"~ ~::' ..... t -- ' ". '. '". 'J ', L ] .... , '~ .... .'. ~ '~'~'' ,, ........ , , f, ..... ,,,, ~ ....... ~" .,,.,_~ ' ,"-- ~ ......... ' - .__. { ....... ~ Cement { . O~ ~.~* .. , Other e_~. em {,. Tan C,m,a',t .. Cer~ent Type (Cla~} Clar~ "G" ' Cl;,~ 13, Cement Amount (s~i 120 Additive~,,.~ ~ ~p,~.',~d,,,%y(T"~e)0.20% .,.,.,,,~" ..... ' -" '- ' 0.20% D45 ,,, ~i"~; r~t~vh'~..~ 4%= ................. s~ .I -'~- ' ' ~ - - ! .... -, _ ~. ! t , .... - ,. , ' , , _, . . ,.._- .- ....... ~'-- , , , .......... - L __. , ..... ' --- . ....... _ Mix Water (91Deirry~e 11.o44 H2~ 5 H20 , ~L ; ' - .. "~ ' ' .'_ ', , u .__ I ~ _ __ ~ _ . " ~ ' _ _ _ _ ~{un~ YieLd .(CuR/s~) 2.01 1.16 ' ~'. ' '; ~,- ,,, .... I .*! .,~ i ii,l_ - __ iml,, : open hNe ~.(~1 ~o 50 -". - - '" ~ .... ,~ ,f ,-, - ;,. , , A! ~ . ' . MARATHON OIL COMPANY- GULF COAST I ~EGION K-I-U246~ F/CSG_CMT. XLS Rev: 9-30-g8 08/15/00 T[~ 11:40 FAX 19075646489 Marathon011 Co 002 CASING AND CEMENTING RECORD ~ r Pi, R. eci meade ' es/No w, r P~ P~iorTo Pre-Flush ee,~lo I Pm-Flush (=er T ~ Pm-Flus~ i Wi er PI0 Prior To Cement .Yes/Na i wi er Pm Prior To Cement Yes/Na J B in Cement Mix Ti~e' hr/rain Cement MixTime hrlmin Dis face With Cement ~n~-~'u~ I D' cement Flukl T I ' la~ement FJukl Wei ht J Dis la.merit Volume bbls . I .. Di aoement Rate Field; Kena[ Ga~ Reid' """: -~"='' ''~- . =d,=ii'': .:.:i;i~: ". :.::-.=.-',-'." "';'.':;.;;.'.!::;:" ..:,-:':'-' ":': ....... ::: :, [ Circulate Time Prfor to Pre-Flush hrs Well: Page 2 of 2 10.5 9:.01 9:34 CU Mad 9.40 220 6.3 KTU 32-7 . Ca~in~ Size:. 7': ~ Mud Lost While CJrculafin bus --~..~.__.~._Mud Lost While Total MI/d Loci bbls Inn~i ~ ~o ~ o H~ ~m~r : Landi Wei ~Sli a ~ 1000 Bum W'~PI Ta si 0 Place Time~ 10:.14 Floats~ Yes Lc~WNle Run~ 0 250 No 50~ 8.5" ! Final Dis lacement PressUre 1538 : Ca=si Landed On tdi ha ~ Iinerhan er~ ~ . SubSea Ha er Lacloin Installed era/No/NA N~/A Lost parfie' I displacement ~:~420Q', Mud Iosse . ' , ' sh~ng la, ndfng jt tO bottom. Lanaed hanaer and ,--.,,,-,,~ ,,, ..... .=__ .. p?cement 5'J~-10% returns wine .... ,~,,,~,. ,,~u re[urns trlmugnout entire job. 16 8111/oo ' Grade Thread 8/1gl00 Grade 29.0 P'~ 10 Eluttress eST. 78 7 23,0 L-SD Buttmss 23.0 L-80 Buttress 5268.62 23, 0 I,-80 Eluttrese :20. 'l 5 275.35 Total 27~.35 Date: .. , 8f1~/00 . KTU246HTCSG_CMT. XLS Rev: g-30-g8 ................ ..0_.8./._0_9,.../..00. ...... .W. BD......0..7.; 16 FAX 19075646459 MarathonOll Co I Fi,,.! · MARATHON OIL COMPANY- OULF COAST REGION CA-~N~ AND CEMEN'I1NG RECORD ; ~'c~ -0~3 ( Page 1 of 2 ii .... I ,.,,, ! ..r,,d I i ,',o,. I ,o RKB to: I G_r_o_L~.p Level " 22.00 . .0.00. 2~.00 · . -- ,jim, . _ 1 ! Cut ~ J,t.. : 9,518" e~' ;L.GO 40~ .... 15.80 22.00 , 37.80 ,,j 35 I Casing _, , .. __ 9 6ir,' , ...... Buttres~ :LBO., , 40~ 1388.62 37.80 1426.42 · t~,. ,. -. 1 I Float Collar. _ . g ~8' ...... 9L~eSS ..... : , ,, !..48 1426.42 1427:90._ ..... ' 2 I'ca, sTngahoe~ , __ .. 9618" , .,~ultre~ , ;La0 4CW 80.37 1427.90 150827 I ] Float Shoe : tt 5f8" Buttm~ , ' "' ' 1.73 i508,27 t5t0.00 ,,. ~,. .. ....... _ ....... · .... I .. ; i __ . · J_,,i, , -,~,, . I ~.___, i ' , i .... ,,. J ._ ' .... .., , ,,, , ! .... ,,- .J~._ ti _ ~,. I ., ._..:',., , , ,. ,, .~. lira , ..... a...,. ,L' I ' ,, h I .. · .. . I ' ' .... i .... , ,. I .... ; ...... ,, ,,, _ ,,1 ji. ~" l' ......... ;.. i. Jr I Ill. '~ . - ....... '---" ~ ~ .I .... :" -- I ............... i -' ..... . .' ......... . ---. . · ... --. , _..-- . .. , , ,, ,., ,,,, , · . dm, d , · , ,m., I I . * ' ..' . ::::""' ' ....... . ..... : ....... :,. :,., ........-'-'"""~"'-"'-" """"'~ ~-~c~rn,,m~,~.Nl; ........... ,,.,.,:: .................... , .... ............ ,,.....: ................ . ................. . ...... : .............. ..:,.:,..~:.,.~ '::'"'::~i~:' h'~h,.:{H~hT~,~.,.~,, ~ , ~,~. I' *~, ...... I ...... . .............. ~ ..' ...... ,. I ~,~ ....,:1 5 I WelciedBowSpdflg Middle lsttwojts,n .c~3 collars ' -i488.00 1325,00 ..... 1 I WalMed Bow Spring .. ....... 1st jt below _~su~ac.. e ...... : ....... . ,11 i , , .... , -~. L ...... I . ~1 - ' *' -- I , ,, il ,, ...... _ i ___ ,.I,"d , il' I , , i , C$~LC~ n[xls MARATHON Oil. COMPANY- eULF COAST REGION Rev: 9-30-98 ~ 001 08/09/00 ....... ~h" Ils ~D 07:17 FAX 19075646489 Marathon011 Co ; i CAS~IG AND CEMENllI~ Kensi Gas Field · Well: ....... .K~..U ~-6 Casing Size: ~_ , g 5/8" Page 2 of 2 ~]002 8fflO0 .......... ; Rev:. 9-30-98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n:~drlCkgf143-6xrd\form403.xls 1. Type of Request: Abandon Suspend Operation Shutdown __ Re-enter Suspended Well. Alter Casing ~ Repair Well Plugging__ Time Extension Stimulate Change Approved Program Pull Tubing Variance Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 39' FNL, 4232' FWL, Sec 7, T4N, R11W, S.M. At top of Productive Interval 2050' FNL, 3402' FWL, Sec 7, T4N, RllW, S.M. At Effective Depth 2050' FNL, 3402' FWL, Sec 7, T4N, R11W, S.M. At Total Depth 2050' FNL, 3402' FWL, Sec 7, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 5. Type of Well: Development ._~.X Exploratory Stratigraphic Service 9535 feet Plugs (measured) 8892 feet 9461 feet Junk (measured) 8821 feet 6. Datum Elevation (DF or KB) 21 feet 7. Unit or Property Name Kenai Unit 8. Well Number KTU 32-7 9. Permit Number 200-023 10. APl Number 50-133-20491-00 11. Field/Pool Kenai Gas Field/Tyonek ORIGINAl. Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 123 13 3/8" Driven true vertical Tubing (size, grade, and measured depth) Measured Depth 123' KB 9 5/8" Circulated 1500' KB 7" 345 sxs 5700' KB 4 1/2" 410 sxs 9422' KB 4 1/2" O.D., 12.6#, L-80, BTC to 5400' KB True Vertical Depth 123' KB 1500' KB 5300' KB 8950' KB i:F :=i..,,. ¢;'. ....... ',~.,,...../..,. ¢i¢ ..... :¢' '""~:' ~* it.,..'~ '~¢ 2000 Packers and SSSV (type and measured depth) ZXP Liner Top Packer @ 5400' KB 13. Attachments Description Summary of Proposal X Detailed Operations Program BOP Sketch 14. Estimated Date for Commencing Operation 115. Status of Well Classification as: 7/12/00 I Oil Gas X Service 16. If Proposal was Verbally Approved Name of Approver Date Approved Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe Craig Young Title Sr. Drilling Engineer [ ,) ~ ( ~ FOR COMMISSION USE ONLY Conditions of Approval: Notify Commi~ion so representative may witness Plug Integrity BOP Test v/ Location Clearance Mechanical Integrity Test Subsequent Form Required 10- ~'~O ? Approved by Order of the Commission Form 10-403 Rev. 06115/88 #564-6310 Date 6~20~00 JAppr°va,~)O .._ ORIGINAL SIGNED BY - --a ",OF SC'''~n' ,nt ? ~o~O~..;~,,~-. ,~ ~ _ Commissioner mit in'Triplicate ( { Marathon proposes to change the approved well casing program as follows: Approved Top Bottom Cement Hole Casing Weight Grade Coupling MD TVD MD TVD Driven 20" 133 K-55 PE 0 0 100 100 17 W' 13 3/8" 61 K-55 BTC 0 0 1500 1500 Circ. 12 %" 9 5~8" 40 L-80 BTC 0 0 5659 5300 345/680 8 ~" 7" 26 L-80 BTC 0 0 9426 8950 554 Proposed Top Bottom Cement Hole Casing Weight Grade Coupling MD TVD MD TVD Driven 13 3/8" 61 K-55 PE 0 0 123 123 12 %" 9 5/8" 40 L-80 BTC 0 0 1500 1500 Circ. 8 W' 7" 26 L-80 BTC 0 0 5659 5300 345 6 1/8" 4 W' 12.6 L-80 BTC 5400' 5035 9426 8950 410 In addition, Marathon proposes to change the surface casing cement to as follows: Type: Class G + 34% Extender + 0.65% dispersant + 0.1% anti-foam +0.3% D-79 Extender Weight: 12.0 PPG Compressive Strength Time(hours) Yield:2.38 cu. ft./sack 500 psi 5:48 Mixed Fluid: 8.066 gal/sack 2000 psi 10:00 Porosity: 45.3% 2900 psi 16:00 IKB=87 feet GL=66 feet I I Max Im 27.39 cleg*ee$ ] I KTU 32-7 Tyonek Development Well 13-318" 61 Ibm/it K-55 driven to 100' I 9-5/8" 53.5 Ibm/it K-55 I Q1500' MD/TVD cmt'd in I 12-114" hole 4-1/2" Chemical Injection Mandrel Q 2000' I Estimated Formation Tops MD TVD Steding 3731 3567 Upper Beluga 4958 4653 Middle Beluga 5676 5304 Lower Beluga 6604 6025 Tyonek 7597 7174 Tyonek 84-6 8758 8335 D-1 Sand 9165 8742 TD 9426 8950 Annulus displaced with Nitrogen. 4-1/2" 12.6 Ibm/It BTC L-80 from surface to 5450' MD I 4-1/2" Baker CMU sliding Sleeve (er GL Mandrel) ~ 5300' - Baker 8-3 Pkr ~ 5400' MD above PBR/Seal Assembly Liner Hanger w/Pkr ¢~ 5450' MD I I 7" OD 26 Ibm/It L.80 5703' MD 15300' TVD cmt'd 8-1/2" Hole 4.1/2" 12.6 Ibm/It Hydri1521 L-80 rmm 5450' MD to 9422' MD 18950' TVD cmt~d in 6-1/8" Hole Marat n Oil Company KTU Kenai Gas Field Pad 41-7 6.5 Miles South of Kenai, Alaska ;}ATE: ',ORIGINATOR: IFILE.., ktu3:i 6/15/2000 Attln~o -7 Marathon proposes to change the approved well casing program as follows: Approved Top Bottom Cement Hole Casing Weight Grade Coupling MD TVD MD TVD Driven 20" 133 K-55 PE 0 0 100 100 17 %" 13 3/8" 61 K-55 BTC 0 0 1500 1500 Circ. 12 %" 9 5/8" 40 L-80 BTC 0 0 5659 5300 345/680 8 ~" 7" 26 L-80 BTC 0 0 9426 8950 554 Proposed Top Bottom Cement Hole Casing Weight Grade Coupling MD TVD MD TVD Driven 13 3~8" 61 K-55 PE 0 0 123 123 12 %" 9 5/8" 40 L-80 BTC 0 0 1500 1500 Circ. 8 ~" 7" 26 L-80 BTC 0 0 5659 5300 345 6 1/8" 4 ~" 12.6 L-80 BTC 5400' 5035 9426 8950 410 In addition, Marathon proposes to change the surface casing cement to as follows: Type: Class G + 34% Extender + 0.65% dispersant + 0.1% anti-foam +0.3% D-79 Extender Weight: 12.0 PPG Compressive Strength Time(hours) Yield:2.38 cu. ff./sack 500 psi 5:48 Mixed Fluid: 8.066 gal/sack 2000 psi 10:00 Porosity: 45.3% 2900 psi 16:00 · ~U~7eiT.'h~ 32-7 Changes Date: Tue, 20 Jun 2000 17:47:22 i" 30 From: "Craig E Young" <CEYoun~,MarathonOil.com> { To: Blair_Wondzell@admin. state. AK. US CC: JGEller~VlarathonOil.com, PKBerga~.MarathonOil.com, RJAffinito~2ClarathonOil.com Per our phone conversation today, attached are the changes in KTU 32-7. I will also submit a Form 403 indicating the changes. If there is anything else I need to do, please let me know. Thanks for your help. Craig Young Senior Drilling Engineer Marathon Oil Company (907) 564-6310 I Name:. CHANGES.DOC ~CHANGES.DOCl Type. MicrosoR Word Document (application/msword) :[Encoding: base64 1 of I 6/20/00 2:52 PM TONY KNOWLES, GOVERNOR ALASi~A OIL AND GAS CONSERVATION CO~I~IlSSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501 -,3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 P. K. Berga Drilling Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 ge~ Kenai Unit KTU 32-7 Marathon Oil Company Permit No: 200-023 Sur Loc: 37'FNL, 4268'FWL, Sec. 7, T4N, RI lW, SM Btmhole Loc. 2050'FNL, 3402'FWL, Sec. 7, T4N, R11W, SM Dear Mr. Berga: 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. hristenson, P.E. Chair BY ORDER OFi~H._~COM'MISSION DATED this day of April, 2000 dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 210 AAC 25.005 .. g:~cmn\drlg~sterllng~su44-10V~OGCCPTD.~Is ~ ~SION la. TypeofWork DrillL~J Re-DrillU lb. Type of well. ExploratoryU StratigraphicTestU Development OilU Re-Entry[--] Deepen~ Servicer~ Development Gas~'~ Single Zone~-~ Multiple Zone~--'~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 87' KB feet Kenai Gas Field/Tyonek 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 A-028142 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 37'FNL, 4268'FWL, Sec. 7, T4N, R1 lW, S.M. Kenai Unit Blanket Surety At top of Productive Interval 8. Well Number Number 2050'FNL, 3402'FWL, Sec. 7, T4N, R1 lW, S.M. KTU 32-7 5194234 At Total Depth 9. Approximate Spud Date Amount 2050'FNL, 3402'FWL, Sec. 7, T4N, R1 lW, S.M. 05/01/00 $200,000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) Property Uric(unit boundary) 12500 feet 1800 feet 6000 9426' MD/8950' TVD feet lS. To be Comp;eted for Deviated Wells 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Kickoff Depth 1500 feet Maximum Hole Angle 28 o Maximum Surface 3089 p$1g at Total Depth (TVD) 8950' 18. Casing Program SetlJng Depth Size Specifications Top Bottom Quantity of Cement Hole Casing W, eight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 PE 80-100' 0' 0' 80-100' 80-100' 17-1/2" 13 3/8' 61 K-55 BTC 1500' 0' 0' 1500' 1500' 1016 sx 12 1/4" 9 5/8" 40 L-80 BTC 5659' 0' 0' 5659' 5300' 345 sx 1st 680 ax 2nd 8 1/2" 7" 26 L-80 BTC 9426' 0 0 9426' 8950' 554 ax gnch0rag0 Kenai Unit well KTU 32-7 will be directionally drilled to an estimated total depth of 9426' md, 8950' tvd from the existing Kenai Gas Field pad 41-7.1he primary production interval will be cased with 7" casing cemented in place and run to surface. Marathon's drilling rig will be used to drill and complete this well. lhe following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit ,r win ,owou, r en,io. ORIGINAl- 20. Attachments Filing FeelXI Property Platl X I BOP Sketchl X I Diverfer Sketchl XI Drilling Programl XI Drilling Fluid Program['X"'~ Time vs Depth Plotr'~ Refraction AnalysisN Seabed ReportN 20 AAC 25.050 RoquirementaN 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Commission Use Only Permit Number ,~)q~,/,,.~;~)l App ro.~.~ ~i~)/{Vql~ JSee Cover Letter .~..C>4:::::) - O ~ 50-- ! ~-~ -- IFor Other Requirement,s Conditions of Approval Samples Required L_JYes ~No Mud Log Required L~Yes L~No Hydrogen Sulfide Measures DYes [~No DireclJonal Survey Required [~Yea DNo I-q,o Other. Approved by Robert N. Chri~f~e~ Commissioner the Commission Date ~ . Form 10-401 Rev. 12-1-85 Sub t in Triplicate Re: Some Questions -Reply _ Subject: Re: Some Questions -Reply Date: Thu, 16 Mar 2000 14:13:57 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: John GEller <jgeiler@marathonoil.oom> CC: Blair Wondzell <blair_wondzell@admin.state.ak. us> Gary, Just a further note regarding what I know of the status of approvals for the proposed work. KU 43-6a .... Sundry approved 399-196, coastal zone not needed KBU 33-6 .... PTD approved 99-24, coastal zone completed KTU 24-6h--PTD approved 99-73, coastal zone completed KTU 32-7 .... approval pending PTD 200-023, coastal zone waived KBU 42-7 .... PTD approved 99-25, coastal zone completed KDU 5 ........ to date, no sundry application received, coastal zone not needed CLU-6 ........ approval pending P'rD 200-033, coastal zone underway GO #1 ........ to date, no P'ID application received, coastal zone in preparation I will move the ~ and CLU-6 PTD applications on through. We can issue the 42-7 without delay since CZ. is not necessary. CLU-6 and ultimately GO #1 can be issued when the respective CZ is received. Thanks again for the info. Tom John GEller wrote: > Tom - I sent you a message a day or two ago that I believe addresses items #,3 (i.e. formation test) and #5 (i.e. BOP test pressure). I'll tryto address the other concerns you brought up. > > #1 & #2 - We do have a rig schedule prepared, and we're planning on doing all our drilling and workover work this year using the same rig. I'll try to get a GANTT chart to you in the near future, but in the mean time here is our best-estimate for the rig schedule: > 1) Well KU 43-6a workover, start March 23 > 2) Well > 3) Well > 4) Well > 5) Well > 6) Well > 7) Well > 8) Well KBU 33-6 drill & complete, start April 8. KTU 24-6h drill & complete, start May 10. KTU 32-7 drill & complete, start June 26. KBU 42-7 drill & complete, start July 28. KDU 5 workover, start August 29. CLU 6 drill & complete, start September 15. Grossim Oskolkoff #1 drill & complete, start October 15. > The order of these jobs is only rock-solid for wells 1-3. The order in which we do jobs 4-8 in very much in flux. That is the reason we gave you identical start dates for CLU 6 and KTU 32-7: ~e want to be able to move to the next well that makes sense without having to wait on permits. But the above schedule is the plan we currently are working under. > > ~/1 - There is a typographical error on page 5 of the drilling programthat was sent you for well KTU 32-7. Including the 50% excess, the top of cement from the second stage will at 2000'. This adequately covers the Sterling Sands, the top of which is at 3567' TVD. My apologies for the error. > > Please/et me know if you have any other questions. > > >>> Tom Maunder <tom_maunder@admin. state, ak. us> 03/14/00 02:58pm >>> > Gary, > Following up with my call of a little bit ago, I have some additional 1 of 3 3/17/00 9:41 Ak,' Some O. ueslions-Reply Tom Maunder AOGCC Subject: Some Questions Date: Tue, 14 Mar 2000 14:58:22 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Gary Eller <jgeller@marathonoil.mm> Gary, Following up with my call of a little bit ago, I have some additional questions and requests. These may be items for Pete. Please forward on if you would, I don't have Pete's eddress. 1. At this morning's meeting, it is apparent that Marathon is planning to be busy. We like that. Could you please send us an anticipated schedule for the activities of your rig or rigs. 2. I am looking at the CLU-6 and KTU 32-7...will they be drilled with the same rig? The same spud date is on each permit application. 3. When drilling out of a casing, our regulations require 20' to 50' of new hole. The programs specify 10' or 5-10'. 4. By the numbers given in the program, it appears that the planned cement height on the 2nd stage of the 9-5/8" casing in KTU 32-7 will not cover the shallowest Sterling sand. 5. BOP test pressures...on each rig 13-5/8" 5000 psi stacks are planned. For CLU-6, the estimated MASP is 1815 psi. Absent Marathon's need for a higher pressure, we would plan to require a 3000 psi BOP test pressure. On KTU 32-7, with the higher IV[ASP, a 5000 psi test would be the requirement. Thanks for the help. Tom Maunder AOGCC m maunder.vdlN_amc: iom maunder.vd - ' ,',i i..,-,i !, ..!YPe:.Plai~...T.ext (text/plain)! 2 of 2 3/16/00 12:02 PM Perm, it-t~-Drill, Well CLU-6 Subject: Permit-to-Drill, Well CLU.6 Date: Tue, 14 Mar 2000 17:57:32-0600 From: "John GEller" <JGEIler@MarathonOil.com> To: Tom_Maunder@admin.state.ak. us CC: CEYoung@MarathonOil.com, JGEIler@MarathonOil.com, PKBerga@MarathonOil.com Tom - Thanks for calling concerning the permit-to-drill application for well CLU-6 in the Cannery Loop Unit. In response to your questions: 1) After running and cementing casing, Marathon will drill 20' to 50' of new formation before conducting a formation integrity test in accordance with 20 AAC 25.030(f). 2) Since the surface pressure during drilling of well CLU-6 is not expected to exceed 1,815 psi, Marathon requests that the BOPE be tested to a maximum of 3,000 psig. Please let me know if I can be of further assistance. I of 1 3/16/001:37 P~ DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: KTU 32-7 PAD: 41-7 SLOT: NA FIELD: Kenai Gas Field AFE No.: 9204900 TYPE: Development. REVISION NO.: 0 DATE: 2/11/00 SURFACE LOCATION: 37' FNL, 4218' FWL, Sec. 7, T4N, R11W, $.M. TARGET,~ Middle Beluga Tyonek BOTTOMHOLE LOCATION: 1637' FNL, 3568' FWL, Sec. 7, T4N, R11W, S.M. 2050' FNL, 3402' FWL, Sec. 7, T4N, R11W, S.M. 2050' FNL, 3402' FWL, Sec. 7, T4N, R11W, $.M. KB ELEVATION: 87 ft. mean S.L. (est.) GL ELEVATION:" 66 ft. mean s.g I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling 3761 3567 Upper Beluga 4958 4653 Middle Beluga 5676 5304 Lower Beluga 6644 6025 Tyonek 7597 7174 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) DEPTH(TVD) Sterling 3761 Upper Beluga 4958 Middle Beluga 5676 Lower Beluga 6644 Tyonek 7597 Tyonek 84-6 8758 Tyonek D-1 9165 TD 9426 3567 4653 ---- 5304- ~5'~1~ 6025 7174 8335 --- 8742 8950 RECEIVED FEB 1 ~ 2000 Nasla 0il & Gas Cons. Commission Anchorage POTENTIAL CONTENT gas/water gas/water gas/water gas/water gas/water gas/water gas/water page 1 g:\cmn\drlg\kgf~wells\ktu 32-7~327prog.xls III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 20" X 3000 psi annular preventer and a 16" O.D. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: 20 3/4" 3M Flange top x 20" weld on bottom for N/U diverter system. CASING HEAD: 13 5/8" 5000 psi top x 13 3/8" sow bottom with base plate for 20". CASING HEAD: 13 5/8" 5000 psi top x 13 5/8" 5000 psi bottom. TUBING HEAD: 11 "-5000 psi top xl 3 5/8" - 5000 psi bottom. RECEIVED FEB 1 2000 0il & Gas Cons. CommisSi.o.n Anchorage CHRISTMAS TREE: 3 1/8" - 5000 psi dual christmas tree including two master valves, one flow tee, one wing valve and one swab valve. page 2 g:\cmn\drlg\kgf~wells\ktu 32-7~327prog.xls IV. CASING PROGRAM: TYPE SIZE CONDUCTOR: 20" CASING DESCRIPTION WT. GRADE 133 ppf K-55 SURFACE: 13 3/8" 61 ppf K-55 INTERMEDIATE 9 5/8" 40 ppf L-80 PRODUCTION: 7" LINER 26 ppf L-80 SET SET HOLE THREAD FROM TO SIZE (md/Nd) (md/Nd) PE Surf 80-100/80- Driven 100 BTC Surf 1500'/1500' 17 1/2" BTC Surf 5659'/5300' 12 1/4" BTC Surf 9426'/8950' 8 1/2" CASING DESIGN SIZE WEIGHT GRADE 13 3/8" 61 ppf K-55 9 5/8" 40 ppf L-80 7" 26 ppf L-80 All tubulars are new. SETTING DEPTH,TVD @ SHOE FRAC GRD FORM PRSS DESIGN FACTORS @ SHOE MASP TENS COLL BURST 1500' 11.0 5300' 14.0 8950' 15.2 702 763 12.20 1.47 4.09 2480 3524 5.02 2.40 1,40 4118 3089 3.12 2.97 2.20 page 3 g:\cmn\drlg\kgf~wells\ktu 32-7\327prog.xls V. CEMENTING PROGRAM SURFACE: 13 3/8" 1500'/1500' LEAD SLURRY- Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: SURFACE 12.8 ppg. 2 cu. ft./sk gal/sk hrs:min 50 % in open hole. 516 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 1263 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % in, open hole. 500 sks. RUNNING . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! Remove thread protectors and visually inspect connections. Make up float shoe and 1 shoe joint. Check float. Fill pipe until circulating. M/U stabin float collar. (Baker-lok all connections to top of float collar) Fill pipe until circulating. Run remaining casing and centralizers. M/U circulating head. Test lines. Circulate until no gain in circulating efficiency is made. Run in. necceme,.n,_tin_cl stdng~ with stabing sub and centralizer. Baker has false rotary and slips. Pump spacer as follows: To be designed. Mix and pump lead slurry. Mix and pump tail slurry. Displace cement. Sting out. Check floats. POOH with inner string. WOC N/D diverter. Weld on casing head and N/U blowout preventers. Test BOPE. Run wear bushing. page 4 g:\cmn\drlg\kgf~wells\ktu 32-7\327prog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 9 5/8" @ 5659'/5300' LEAD SLURRY: Class "G" + required additives. Stage I Stage 2 TOP OF CEMENT: 5170 ft. 3908-% WEIGHT: 12.8 ppg. "';~-~-- £ -12.8 ppg. ~'~'~(" YIELD: 2.00 cu. ft./sk 2.0 cu. ft./sk WATER REQ.: gal/sk gal/sk PUMPING TIME: hrs:min hrs:min EXCESS (%): 50 % 50 % ESTIMATED VOLUME: 0 sks. 680 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: 5600 ft. 4925 ft. WEIGHT: 15.8 ppg. 15.8 ppg. YIELD: 1.15 cu. ft./sk 1.15 cu. ft./sk WATER REQ.: gal/sk gal/sk PUMPING TIME: hrs:min hrs:min EXCESS (%): 50 % 50 % ESTIMATED VOLUME 345 sks. 0 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1.Remove thread protectors and visually inspect connections. 2.Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating.. 3.M/U float collar. (Baker-lok all connections to top of float collar) 4.Fill pipe until circulating. 5.Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6.Circulate and reciprocate until no gains in circulating efficiency is made. 7.Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500, psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U casing spool and test. N/U BOP stack. 15. Test BOPE. page 5 g:\cmn\drlg\kgRwells\ktu 32-7\327prog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 7"@ 9426'/8950' LEAD SLURRY' Class "G" + required additives. TOP OF CEMENT: ft. WEIGHT: ppg. YIELD: cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): %(use 25% over caliper log.) ESTIMATED VOLUME: sks. rAIL SLURRY- Class "G" + required additives. TOP OF CEMENT: 5700 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 25 % over caliper log. ESTIMATED VOLUME 554 sks. RUNNING . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! Remove thread protectors and visually inspect connections. Make up float shoe and 2 shoe joints. Check float. Fill pipe until cimulating. M/U float collar. (Baker-lok all connections to top of float collar) Fill pipe until circulating. Run remaining casing. M/U cementing head and test all lines. Circulate until no gains in circulating efficiency is made. Drop bottom plug and begin pumping spacer. Pump spacer as follows: To be designed Mix and pump tail slurry. Drop top plug. Displace cement. Bump plug with 500 psi. over displacement pressure Check floats. WOC. N/U tubing spool and test. Test BOPE. page 6 g:\cmn\drlg\kgf~wells\ktu 32-7\327prog.xls VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO TVD ppg sec/qt LOSS TYPE 0' 1969' 8.6-9.0 80-250 15-30 Freshwater gel 1969' 5300' 8.6-9.0 42-80 <8 FLO PRO/KCL 5300' 8950' 9.0-9.5 50-70 <5 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to dewater the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. · VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM CONDUCTOR: SURFACE: PRODUCTION: COMPLETION: No logging is planned for this interval. No logging is planned for this interval. RUN #1: AIT/DSI/LDT/CNL/GR. RUN #2: CMR/AIT/MSFL/LDT/CNL/NGT. Gammaray/CCL. RUN #3: RFT/GR. RUN #4: MSCT/GR. MUD LOGGING The well will be mud logged from 2000' md(casing point) to TD at 9426' md. _ CORING PROGRAM A 30' conventional core will be cut in the 84-6 sand. TESTING PROGRAM No open hole tests are planned for this well. page 7 g:\cmn\drlg\kgRwells\ktu 32-7\327prog.xls VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS See attached sheet for anticipated bottomhole pressures for all sands. Lost returns are possible. Hydrogen sulfide gas has not been encountered in any well in the Kenai Gas field IX. OTHER INFORMATION DIRECTIONAL PLAN SOUTH WEST DESC MD TVD INCL AZIM COORD COORD VERT SECTION RKB 0 0 0 0 0 0 KICKOFF 1500 1500 0.0 225.0 0 0 build @ 2.5 deg/100ft HOLD 2617 2573 28.0 201.9 259 111 DROP 5703 5300 28.0 201.9 1600 650 END of DROP 7565 7088 0.0 201.9 2013 816 Total Depth 9426 8950 0.0 201.9 2013 816 0 282 1727 2172 2172 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) DEPTH (MD) KU 43-6 44 1020 KU 13-5 28 1180 KBU 42-7 62 1220 KTU 24-6H 40 1625 page 8 g:\cmn\drlg\kgf~wells\ktu 32-7\327prog.xls X. DRILLING PROGRAM CONDUCTOR: Drive 20" conductor to +-100 ft. RKB. Weld starting flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 20" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 17 1/2" hole to 1500' md/1500' tvd per the directional plan. Run and cement 13 3/8" casing. WOC. Cutoff 13 3/8" and 20". Weld on 13 3/8" SOW by 13 5/8" 5M wellhead and test. N/U 13 5/8" 5M BOP'$. Test BOP'S and choke manifold to 250/3000 psi. Set Wear bushing. Test surface casing to 1500 psi. INTERMEDIATE Drill out float equipment and make 5-10' of new hole. CBU. Test shoe to leak off. Estimated EMW is 11.5 ppg. Drill 12 1/4" directional hole to 5659' md/5300' tvd as per directional plan. Lost cimulation is possible through this entire interval. Make wiper trip. Run and cement 9 5/8" casing. WOC. N/U 13 5/8" 5M x 13 5/8" 5M head. Test BOPE to 250/5000 psi. Set wear bushing. Test casing to 3600 psi. PRODUCTION: Drill float equipment and 1 '(~of new formation w/8' 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 14 ppg. Drill a 8 1/2" directional hole from 5659'md/5300' tvd to 9426' md/8950' tvd' per the directional program. Log. Make a wiper trip. Pull wear bushing. Run and cement 7" casing. N/D and N/U tubing spool. Test BOPE to 250/5000 psi. Test casing to 3100 psi. COMPLETION: Complete well as per comletion program. page 9 g:\cmn\drlg\kgf~wells\ktu 32-7\327prog.xls X. POTENTIAL HAZARDS Well KTU 32-7 To comply with state regulations the Potential Hazards section and the well shut in procedures must be posted in the drillers dog house. The man on the brake(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 3567' tvd/3761' md to total depth of the well. These sands will range from normal pressured to severly depleted and lost circulation and differential sticking are potential hazards. The Flopro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. Minor well interference hazards exists from surface to 1625' md. page 10 n:\drlg\kgf\wells\ktu 32-7~327prog.xls NOTES: MASP CALCULATIONS: Surface casing: 13 3/8" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (11.0 ppg + 1.0 ppg) x .052 x 1500' - (.115 x 1500') MASP = 936 psi - 173 psi MASP = 763 psi. Intermediate casing: 9 5/8". MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (14.0 ppg + 1.0 ppg) x .052 x 5300' - (.115 x 5300') MASP = 4134 psi - 610 psi MASP = 3524 psi. Production casing: 7". MASP = Formation pressure(producing zone) - Hydrostatic pressure of gas column. MASP = 9.0 ppg x .052 x 8750' - (.115 x 8750') MASP = 4095 psi - 1006 psi MASP = 3089 psi. Cementing The 13 3/8" casing must be cemented to surface. Contact AOGCC and BLM in advance to see if they want to witness the cement job. The cementing of the 9 5/8" casing may or maynot be done in stages. The actual procedure and amount of cement will be determined once the severity of lost cirulation is determined. BOP/Diverter Tests. Contact AOGCC and BLM a minimum of 24 hrs prior to tests to see if they wish to witness. Tubulars All tubulars are new. page 10 g:\cmn\drlg\kgf~wells\ktu 32-7~327prog.xls Marathon Oil Well KTU 32-7 Choke Manifold Gas Buster ITo Blooey Line IBleed offLineto I Shakers 2 9/16" 1 OM Swaco Hydraulically Operated [From BOP Stack Choke 3 1/8" 5M Manually Adjustable Choke Marathon Oil Well KTU 32-7 Diverter Flow line 20 3/4" 3M Diverter IDiverter Spool 6" Automatic Hydraulic Valve 6" Diverter Line Marathon Oil Well KTU 32-7 BOP Stack I FIow Nipple 13 5/8" 5M Annular Preventer IFl°w Line I J I 13 5/8" 5M Double Ram Preventer 3 1/8" 5M Manually Operated Valves 13 5/8" 5M Single Ram Preventer IPipe Ram I IBlind RamI IPipe Ram I 3 1/8" 5M Hydraulically Operated Valve Operated Valve MARATHON Oil Company Sfmotum: Pad 41-7 Well: KTU32-7 field: Kenai Gas Field Looatlon: Kenai Peninsula, Alaska 5O0 1000 15OO 2OOO 2500 3000 ~500 4000 4500 5000 [_. 5500 I V. 6000 6500 7000 7500 8000 8500 9000 Beg|n Nudge 1.50 3.00 End Nudge KOP 2.50 7.50 12.50 DIS: 2.50 deg per 100 ft 17.50 22.50 27.50 WELL PROFILE DATA <- West (feet) looo .oo 6oo 400 2o0 o I I I I I I , I I I I Top Middle Belug~ 1-30-00 27.00 28,.00 21.00 18.00 15.00 DLS: 1.50 deg per 100 fi 12.00 9.00 6.00 3.00 0.00 Below Tyonek 01 1-30-00 ~ i i ii i ii i ii I 0 500 1000 1500 2000 2500 Vertical Section (feet) -> Azimuth 202.11 with reference 0.00 N, 0.00 [ from slot 1~$2-7 Top Middle Beluga 1-50-00 Below Tyonek D1 1-30-00 200 400 600 800 0 1000 1200 ~ I V 1600 1800 2000 2200 Creel:ed by Sutherlond For: P. OcRe pk)t.l~l: 15-Feb-2000 Plot Referanoe la KTU 32-7 Vendm Coon~notes ore in ~ rate.rice ,dot /~.--7. Tm. Ver~i~l D~th~ o~mnc~ FJt; RKB.I MARATHON Oil Company Structure: Pad 41-7 Well: KTU32-7 Field: Kenai Gas Field Loaafion: Kenai Peninsula, Alaska <- West (feet) 2200 2000 1800 1500 1400 1200 1000 BOO 600 400 200 0 200 400 600 800 400 {~ 4O0 \ 1750 200 \ 200 1500 2000 0 1250 0 200 2500 000 200 / 1500 1750 400 ~'~ 1500 400 ~2500 O0 1750 ~5250 1000 ~750 600 6O0 ~4~25o / ~ 3000 ~,~4500\. / 5500 1250 \~5250 800 ~x~750 ~ 5750 1500 ~ 5500 80O 0 ~ 4000 0 75O ! 1750 57 ~4250 602~§'~ '---" / ~ 4500 2000 85oo~. / 6750'~_~ ~ 4750 2250 / ~ 5000 / 2500 1000 ~ 1200 -I-- 0 1400 I V ~6oo 4250 ~250 i 525O / t500 f 5500 2750 1800 ~750 ~5750 1800 /6000 5000 2 . 6250 ooo '5500 3250 2200 ~ 22O0 O0 ~500 - /s25o 2400 - .,~500 2400 ,'~50 3750 2600- 2500 - 4000 2800- I 2800 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 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 600 800 <- West (feet) 3750 ~ 4000 1000 ~ ~, 4250 0 4500 .-,. 5000 1200 ~ 1400 ~ I 1~oo V O~ted b,j Suth~dand For: P. Date plotted: 15-Feb-2000 Plot Rel'emnce Is KTU 32-7 Vemion :aaraln,,t~s om ;n hint mf. mnce 'dot t32-7.I Tree Vertical Dsl)th. om mfemm~ Eld: RKB. I 2200 330 320 310 MARATHON Oil Company Structure: Pad 41-7 field: Kena; Gas field Well: KTU32-7 Looafion: Kanai Pen;nsula, Alaska 35O TRUE NORTH 1500 2500 20 40 3O0 29O 7O 28O 80 270 26O --I,- 90 lO0 25O 110 240 120 2'30 220 210 2OO 130 170 160 1 40 ~00 2200 2]o-~~Foo_.~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well HARATHON 0il Company Pad 41-7 KTU32-7 slot #32- 7 Kenai Gas Field Kenai Peninsula, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: KTU 32-7 Version Our ref: prop3865 License : Date printed: 15-Feb-2000 Date created: 30-Jan-2000 Last revised: 15-Feb-2000 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on 270908.300,2362070.010,999.00000,N Slot location is n60 27 33.911,w151 1444.878 Slot Grid coordinates are N 2361973.347, E 275123.210 Slot local coordinates are 15.42 S 4216.16 E Projection type: alaska . Zone 4, Spheroid: Clarke - 1866 Reference North is True North MARATHON Oil Company Pad 41- 7, KTU32- 7 Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin. Azimuth TrueVert R E CTANGU LAR Depth Degrees Degrees Depth C OORD I NATES PROPOSAL LISTING Page 1 Your ref: KTU 32-7 VersionS2 Last revised : 15-Feb-2000 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 h 0.00 E 0.00 0.00 500.00 0.00 0.00 500.00 0.00 N 0.00 E 0.00 0.00 600.00 1.50 225.00 599.99 0.93 S 0.93 W 1.50 1.21 700.00 3.00 225.00 699.91 3.70 S 3.70 W 1.50 4.82 750.00 3.75 225.00 749.82 5.78 S 5.78 W 1.50 7.53 800,00 3,00 225,00 799,74 7,86 S 7.86 W 1.50 10,25 900,00 1,50 225,00 899,66 10,64 S 10,64W 1,50 13,86 1000,00 0.00 225.00 999,64 11,57 S 11,57 W 1,50 15,07 1500.00 0,00 225,00 1499.64 11.57 S 11,57 W 0,00 15,07 1600.00 2.50 201.90 1599.61 13.59 S 12.38 W 2.50 17.25 1700,00 5,00 201,90 1699,39 19,66 S 14,82 W 2,50 23,79 1800,00 7.50 201,90 1798,79 29,76 S 18.88W 2,50 34,68 1900,00 10,00 201,90. 1897,62 43,87 S 24.55 W 2.50 49.89 2000.00 12.50 201,90 1995,69 61,97 S 31,83 W 2.50 69,39 2100.00 15,00 201,90 2092.81 84.03 S 40.69 W 2,50 93,16 2200,00 17,50 201,90 2188,81 109,99 S 51,12 W 2.50 121.14 2300.00 20,00 201,90 2283.50 139,81 S 63.11 W 2,50 153,28 2400,00 22,50 201,90 2376.69 173,44S 76,63 W 2,50 189,52 2500.00 25,00 201,90 2468,21 210,80 S 91.65 W 2.50 229,80 2600.00 27,50 201,90 2557,89 251,84 S 108,14 W 2,50 274,02 2616,77 27,92 201,90 2572.74 259,07 S 111,05 W 2,50 281,82 3000,00 27,92 201,90 2911,36 425.57 S 177,96 W 0,00 461,26 3500.00 27,92 201,90 3353,17 642,79 S 265,27 W 0,00 695.37 4000,00 27.92 201.90 3794,97 860,02 S 352,58 W 0,00 929,48 4500,00 27,92 201,90 4236,78 1077,24 S 439.89 W 0,00 1163,59 5000.00 27.92 201.90 4678.58 1294.46 S 527.20 W 0.00 1397.70 5500.00 27.92 201.90 5120.39 1511.69 S 614.51 W 0.00 1631.81 5703.27 27.92 201.90 5300.00 1600.00 S 650.00 W 0.00 1726.99 5764,56 27,00 201,90 5354,38 1626,22 S 660,54 W 1,50 1755,25 5864,56 25,50 201,90 5444,06 1667,26 S 677,03 W 1,50 1799,48 5964.56 24.00 201.90 5534.87 1706.10 S 692.65 W 1.50 1841.34 6064.56 22.50 201,90 5626,75 1742,73 S 707,37 W 1,50 1880,81 6164,56 21.00 201,90 5719,63 1777,11 S 721.18 W 1,50 1917,87 6264,56 19,50 201,90 5813,45 1809.22 S 734,09 W 1,50 1952,48 6364.56 18.00 201.90 5908.14 1839.05 S 746.08 W 1.50 1984.62 6464.56 16.50 201.90 6003,64 1866,56 S 757,14 W 1,50 2014,28 6564,56 15,00 201,90 6099,88 1891,75 S 767.26 W 1,50 2041,42 6664,56 13,50 201,90 6196,80 1914,59 S 776,44W 1.50 2066,03 6764,56 12.00 201,90 6294,33 1935,06 S 784,67 W 1,50 2088,10 6864,56 10,50 201,90 6392.41 1953,16 S 791,95 W 1,50 2107,61 6964.56 9.00 201.90 6490.96 1968.88 S 798,26 W 1,50 2124.54 7064.56 7.50 201.90 6589.92 1982.19 S 803.61 W 1.50 2138.89 7164,56 6,00 201,90 6689,22 1993,10 S 808,00 W 1,50 2150,65 7264,56 4,50 201.90 6788,80 2001,58 S 811,41W 1,50 215~,80 7364,56 3,00 201,90 6888,59 2007,65 S 813.85 W 1.50 2166.34 7464,56 1,50 201.90 6988,51 2011,30 S 815,31W 1,50 2170,26 7564,56 0,00 201,90 7088,49 2012,51 S 815,80 W 1.50 2171,57 8000,00 0.00 201,90 7523,94 2012,51 S 815,80 W 0,00 2171.57 8500.00 0,00 201.90 8023,94 2012,51 S 815,80 W 0,00 2171,57 9000,00 0,00 201,90 8523.94 2012,51 S 815,80 W 0.00 2171,57 Top Middle Beluga 1-30:00 RE'CEIl/ED FEB 18, £vUU Oil & ~as Cons. Anchorage All data is in feet unless otherwise stated. Coordinates from slot#32-7 and TVD from Est RKB (87.00 Ft above mean sea level). Bottom hole distance is 2171.57 on azimuth 202.07 degrees from wellhead. Total Dogleg for wellpath is 63.34 degrees. Vertical section is from wellhead on azimuth 202.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON 0il Company Pad 41- 7. KllJ32- 7 Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin. Azimuth TrueVert RECTANGULAR Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref: KTU32-7 VersionS2 Last revised: 15-Feb-2000 Dogleg Vert Deg/lOOft Sect 9276.06 0.00 201.90 8800.00 2012.51 S 815.80 W 0.00 2171.57 9426.06 0.00 201.90 8950.00 2012.51 S 815.80 W 0.00 2171.57 All data is in feet unless otherwise stated. Coordinates from slot#32-7 and TVD from Est RKB (87.00 Ft above mean sea level). Bottom hole distance is 2171.57 on azimuth 202.07 degrees from wellhead. Total Dogleg for wellpath is 63.34 degrees. Vertical section is from wellhead on azimuth 202.11 degrees. Calculation uses the minimum curvaturemethod. Presented by Baker Hughes INTEQ MARATHON 0il Company Pad 41- 7, KTU32- 7 Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Your ref: KTU 32-7 VersionS2 Last revised: 15-Feb-2000 Cnmments in wellpath .... MD TVD Rectangular Coords. Comment 5703.27 5300.00 1600.00 S 650.00 W Top Middle Beluga 1-30-00 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Below Tyonek D1 1-30 8800.00 2000.00S 750.00W 30-Jan-2000 Top Middle Beluga 1- 5300.00 1600.00S 650.00W 30-Jan-2000 RECEIVED FF_B IS 2000 Al,,~,,~ Oil & Gas Cons. ComF,~ission Anchorage Xm DRILLING PROGRAM CONDUCTOR: Drive 20" conductor to +-100 ft. RKB. Weld starting flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 20" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 17 1/2" hole to 1500' md/1500' tvd per the directional plan. Run and cement 13 3/8" casing. WOC. Cutoff 13 3/8" and 20". Weld on 13 3/8" SOW by 13 5/8" 5M wellhead and test. N/U 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3000 psi. Set Wear bushing. Test surface casing to 1500 psi. INTERMEDIATE Drill out float equipment and make 5-10' of new hole. CBU. Test shoe to leak off. Estimated EMW is 11.5 ppg. Drill 12 1/4" directional hole to 5659' md/5300' tvd as per directional plan. Lost circulation is possible through this entire interval. Make wiper trip. Run and cement 9 5/8" casing. WOC. N/U 13 5/8" 5M x 13 5/8" 5M head. Test BOPE to 250/5000 psi. Set wear bushing. Test casing to 3600 psi. PRODUCTION: Drill float equipment and 10' of new formation w/8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 14 ppg. Drill a 8 1/2" directional hole from 5659'md/5300' tvd to 9426' md/8950' tvd' per the directional program. Log. Make a wiper trip. Pull wear bushing. Run and cement 7" casing. N/D and N/U tubing spool. Test BOPE to 250/5000 psi. Test casing to 3100 psi. COMPLETION: Complete well as per comletion program. page 9 g:\cmn\drlg\kgf~wells\ktu 32-7\327prog.xls SURFACE USE PLAN FOR WELL KTU 32-7 Surface Location: NE 1/4 of NE 1/4, Sec. 7, T4N, R11W, S.M. 1. Existing Roads ! 1 1 Bm 1 m Existing roads that will be used for access to the Kenai Gas Field well KTU 32-7 is shown on the attached map. Kenai, Alaska, is the nearest town to the site and is also shown on the map. Access Roads to be Constructed or Reconstructed No new roads will be required to access KTU 32-7. Location of Existing Wells Well KTU 32-7 will be drilled on pad 41-7 in the Kenai Gas Field. A pad drawing is attached that shows existing wells and the proposed location for KTU 32-7. Location of Existing and/or Proposed Facilities The location of existing production facilities in the Kenai Gas Field are shown on the attached pad drawing. These facilities will be upgraded to handle the additional gas production. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. Construction Materials No road or pad modifications or improvements are planned. Method of Handling Waste Disposal a) Mud and Cuttings AJas~-~ Oil & Gas Cons. C0~miss[on Anchorage Cuttings will be dewatemd on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No. 9, Permit ~81-176). \~,LARSO I\COMMON~D RLG\KG~WELLS\ktu32-7~SU RFUSE.doc Surface Use Plan Well KTU 32-7 Surface Use Plan Page 2. al gal 10. b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption, Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. Plans for Reclamation of the Surface Well KTU 32-7 will be drilled from an existing pad. Reclamation of the pad ~/ill occur after abandonment of KTU 32-7 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from CIRI Native Corporation prior to any reclamation work beginning. Surface Ownership The surface owner of the land in the Kenai Gas Field is the CIRI Native Corporation. 11. Operator's Representative and Certification Surface Use Plan ( Well KTU 32-7 Surface Use Plan Page 3 I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of rny knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: ~.//?/~oo, t -'~-/~Mara~r~hon Name & Title: ~"//';7 ~~,'~-~,~/~,~l'"- Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 I I L ' i 'KIXPlY 3' X .... I· 5V ~L. A-61~ PT 5V" gL A.60O. PT ., · , ]3TA ,,, .. U 'TIIBB4 L" il ibld pn.L ."i Col.: 1110' !!'!ÆŒ MARATHON OIL COMPANY ALASKA REGION KENAI KENAI, ALASKA 2000 KBU 32-7 ESTIMATED TOPS AND PRESSURES* 2/14/00 LOWEST PRESSURE LOWEST TOP SSTVD TVD GRAD. PRESSURE STERLING A8 3480 3567 0.08 285 A9 3520 3607 0.08 289 Al0 3570 3657 0.08 293 All 3630 3717 0.08 297 B1 3678 3765 0.08 301 B2 3736 3823 0.08 306 B3 3800 3887 0.08 311 B4 3855 3942 0.08 315 B5 4038 4125 0.31 1279 Cl 4334 4421 0.08 354 C2 4505 4592 0.08 367 HIGHEST PRESSURE HIGHEST GRAD. PRESSURE 0.25 986 NEARBY BELUGA COMPLETIONS KBU 41-7 KBU 13-8 KBU 31-7RD KBU :31-7 BELUGA U1 4566 4653 0.08 372 0.11 512 U2 4613 4700 0.08 376 0.11 517 U3 4661 4748 0.08 380 0.11 522 U4 4678 4765 0.08 381 0.11 524 US 4726 4813 0.08 385 0.11 529 U6 4762 4849 0.44 2134 U7 4813 4900 0.08 392 0.11 539 U8 4871 4958 0.08 397 0.11 545 U9 4899 4986 0.08 399 0.11 548 U10 4978 5065 0.08 405 0.11 557 Ull 5117 5204 0.08 416 0.11 572 U12 5178 5265 0.08 421 0.11 579 U13 5205 5292 0.44 2328 M1 5217 5304 0.2 1061 0.44 2334 M2 5263 5350 0.44 2354 M3 5295 5382 0.2 1076 0.44 2368 M4 5364 5451 0.44 2398 M5 5497 6584 ~2 1117 0.44 2457 M6 5593 5680 0.2 1136 0.44 2499 M7 5611 5698 0.44 2507 M8 5648 5735 0.2 1147 0.44 2523 M9 5684 5771 0.44 2539 M10 5704 5791 0.44 2548 Mll 5733 5820 0.44 2551 M12 5750 5837 0.44 2568 M13 5776 5863 0.2 1173 0.44 2580 M14 5862 5949 0.2 1190 0.44 2618 M15 5924 6011 0.44 2645 L1 5938 6025 0.46 2772 L2 5950 6037 0.46 2777 L3 6000 6087 0.18 1096 0.46 2800 1.4 6080 6167 0.18 1110 0.46 2837 L5/6 6196 6283 0.46 2890 L7 6270 6357 0.46 2924 L8 6330 6417 0.46 2952 L9 6346 6433 0.18 1158 0.46 2959 L10 6420 6507 0.18 1171 0.46 2993 Lll 6592 6679 0.18 1202 0.46 3072 L12 6662 6749 0.18 1215 0.46 3105 L13 6743 6830 0.18 1229 0.46 3142 L14 6800 6887 0.18 1240 0.46 3168 L15 6808 6895 0.46 3172 L16 6854 6941 0.18 1249 0.46 3193 L17 6907 6994 0.18 1259 0.46 3217 L18 6922 7009 0.18 1262 0.46 3224 TYONEK 7087 7174 0.46 3300 72-8 . 7107 7194 0.37 2662 0.46 3309 73-1 7197 7284 0.37 2695 0.46 3351 75-8 7410 7497 0.37 2774 0.46 3449 75-7 7460 7547 0.46 3472 x x x x x x x x x x x CASING POINT x x x x x x x x KDU2 K'ru KOU 2 KDU 2 KTU 1~-5 KTU 43-6XRD 84-6 8248 8335 0.46 3834 86-4 8465 8552 0.46 3934 D-1 Sand 8655 8742 0.37 3235 0.46 4021 TOTAL DEPTH 8863 8950 *Middle and Lower Beluga depletions possible In zones Identified by "X" in the nearby wells. Sterling and Upper Beluga depletions expected across the field. KDU 4RD KBU 3.1-7 CONTROL Used Ihis horizom etruclure Used U. Beluga Midpoint Structure and KBU 41-7 well Used M. Beluga Structure and KBU 41-7 well Used L. Beluga Stuctum aed KBU 31-7 well Used Top Tyonek Stucture and KBU 41-7 well · # # · Used Tyonek 75-8 Stucture Used Tyonek 75-8 Stucture and KDU 4RD Used Tyonek D.1 Sand Structure and KDU 4RD · Used Tyonek I).1 Sand Structure o:~Beluga Sands 1998~tu-32-7~FE'~32-7tops.xls DLB 2/15/00 ¢OoA. :,l-- .iD ,.t~. > I I I . --1--A ---4 ' :i),.), )' · '~ · ..~ i.._s- "' ' ' ~" ~-i~: . ti I I' ' · : ;::11:,~ i II,,~1 JJ ~ ~. -'lJ'll KE~U 33-6 KE~U 42-7 KTU 24-6H KTU 32-7 DI~'"'-~ ' I ~ ~_ ~.a~.o~...._____~ '.1".' ' I'.. : ' :.' ... ' I ' '"' ' " . .}............,,-... ' . ' . . ' .. ' .~,.~~..' . . . . . '. . ,, , .,._=:.,. ,,.. -~,, .~~?-- ...~ .. .. +~~""~ .~... :.~.- ~',, . . ~ ;.. ~~~.~'. . ~. .-..... , . ~1.,,.~,~.' ~ .... ~', . ' , ~ ' "~r',',, ~':' ~' ~.~ ..... ..f .~... .... ... .. . ...... . ,. . . ,,.. ~a..~, . . ~,.~, ~.~.~ _" . " ~1: I~.~- ~ ,~ . ~ '~' ~:', ~,., " . t ~ , . ~,, ~,X,. " . . . ~,..~..' ~ ..... ~'- .~ '.. . .. . ~ ~.~ . ~,,~...'a . ~,"~'" ~,. ,. ,.. . / ~~ ~~. ,. .. . . . .. z ~~ ~ ~ ~,~:'. x~x .I 1 ~... ~ _. ~~.~ ~ ~ ~'. ~ ,. '. .. .. DETAIL t2 8 ~ 7 o r~ m~. (~ m mam~ a ~.~,t~' ' RECEIVED ~-,- ~.- -,~ ' ' "N~.s~ Oil & Gas Cons. Coml~]SS|O.tl ~i;a.. Anchorage a).,~,~.~ ~ m.~,~ , ~ ~ ~.~.~ A~ ~ d ~,~.. ~) ~~,. 8) T~ ~-m ~ ~ P~. ~ ~0 ~ ~ ,~. ,..,,, 011 CPompally ,,.,,. ,,,,,. I I t~m,~,wlmm. I(~IN. ~ ~ PAD &~T ~ J~mdU ~A8, J~LD .PAD 41-7 Alaska ~i' 3n Domestic r'roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 16, 2000 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Kenai Unit KTU 32-7 Dear Mr. Johnston' Enclosed is the application for permit to drill the referenced well and a check for $1oo. Please advise if additional information is required. Sincerely, P. K. Berga Drilling Superintendent PKB:nrs N:\DRLG\KGF~WELLS\kbu33-6\aogccclt.doc Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. :..~O,M~,EV. 4,~7.. ' . Marathon Oil Company Pay tO::=the order..Of: .... ' ANCHORAGE ALASKA " "~aska.i,'.:O~"l'" & Gas Conserva~-~on Commission ::':.?: .... :::!!~h~e,i~.....9.95.0.1.- 31. _9. 2 ................. ~ .................... ..7~:::..?~..,,:,~:. ~: ~.. .'::.'Jili:!? ?':.i'":'=' .:........ '. ~ ............................................................................................... ,. ::, i ::.:!:-:.7:.:':'..:.%'.' ''= .=. :"' o/ L oo MATCH AMOUNT IN WORDS 'WITH NUMBERS - . ..' .'00/-h ?0,' .... 85 8000 5 · . Marathon Oil ComPany ' P.O. Box 196168 02/].6/00 $].00.00 OPERATOR -- INDICATE CITY OR TYPE OF PAYMENT STATE _ _ NON-REPOR31NG 100% REPORTABLE INTEREST RENTS SERVICES NON-EMPLOYEE PRIZES, ~ekRDS, OR DN~GE$ WELL PERMIT CHECKLIST FIELD & POOL Cf/ ¢<~' ~"7~::~ INIT CLAS,~.~EL,/ f~/~._~ ADMINISTRATION DATE ~. {. ~ COMPANY //~/~-/~-r'~"//,~,l, WELL NAMEJ~/'7-~ ~Z-7 PROGRAM: exp GEOL AREA ENGINEERING DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~(3r~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. dev ~/' redrll serv wellbore seg ann. disposal para req ~'? ~ UNIT# O-5 '/1 ON/OFF SHORE Y N N N GEOLOGY 30. 31. 32. 33. AP~.R DATE ~ ~. /. ~c~ 34. Permit can be issued wlo hydrogen sulfide measures.. Data presented on potential overpressure zones ~ Y N Seismic analysis of shallow gas zones .......... ,....?.~ Y N Seabed condition survey (if off-shore) .........../t/r/ Y N Contact name/phone for weekly progress reports [exploratory only] Y N xO/~7 ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N . APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlClAnnular COMMISSION: Comments/Instructions: O Z 0 c:\msoffice\wordian\diana\checklist (rev. 02/17/00)