The URL can be used to link to this page

Home My WebLink About177-029Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/8/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-08 50133203040000 177029 10/11/2023 AK E-LINE TUBING CUT KBU 14-6Y 50133205720000 207149 10/24/2023 AK E-Line PLUG/PERF MPU B-28 50029235660000 216027 1/10/2024 HALLIBURTON MFC40 MPU F-65 50029227520000 197049 1/19/2024 HALLIBURTON MFC40 MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag Please include current contact information if different from above. T38488 T38489 T38490 T38491 T38492 T38493 2/8/2024 KBU 13-08 50133203040000 177029 10/11/2023 AK E-LINE TUBING CUT Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.08 10:05:37 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240112 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL Please include current contact information if different from above. T38273 T38275 T38277 T38278 T38279 T38280 T38280 T38281 T38282 T38283 T38284 T38285 T38286 T38287 T38287 T38288 T38288 T38289 T38289 T38289 T38290 T38290 1/18/2024 KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 11:52:00 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-8 50133203040000 177029 11/15/2023 HALLIBURTON EPX NCIU A-17 50883201880000 223031 11/28/2023 HALLIBURTON RBT PBU 04-46A 50029224340100 223082 11/1/2023 HALLIBURTON RBT PBU 05-26A 50029219840100 201221 11/24/2023 HALLIBURTON PPROF PBU 06-20B 50029207990200 223075 10/18/2023 BAKER MRPM PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT PBU N-07A 50029201370100 204105 10/7/2023 BAKER SPN PBU P1-08A 50029223840100 202199 9/22/2023 BAKER SPN PBU P2-56 50029226100000 195162 11/14/2023 BAKER SPN PBU P2-57A 50029221830100 202214 11/1/2023 BAKER SPN Please include current contact information if different from above. T38205 T38206 T38207 T38208 T38209 T38210 T38211 T38212 T38213 T38214 12/6/2023 KBU 13-8 50133203040000 177029 11/15/2023 HALLIBURTON EPX Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.06 14:25:58 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: * Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,770 feet See Schematic feet true vertical 7,664 feet N/A feet Effective Depth measured 5,515 feet See Schematic feet true vertical 4,617 feet See Schematic feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 12.6# / L-80 5,051' MD 4,225' TVD SS 3-1/2" 9.2# / N-80 5,595' MD 4,586' TVD Tubing (size, grade, measured and true vertical depth) LS 2-7/8" 6.4# / N-80 4,686' MD 6,487' TVD Packers and SSSV (type, measured and true vertical depth) See Schematic See Schematic N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Burst Collapse 1,540psi measured Packer Conductor Surface Intermediate 20 13-3/8" 114' 2,505' TVD 2,505' 2,276' Plugs Junk measured Length * Convert to Gas Storage Production Well measured true vertical 5,123' 7,674' 7" 8,770' 5,122' 4,284' 114' Storage Pool Report Code is 448809. 4,760psi 3,090psi 6,870psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 177-029 50-133-20304-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA022330, FEDA028142 Kenai / Sterling 6 Gas Storage Kenai Beluga Unit (KBU) 13-08 Gas-Mcf MD 0 Size 114' 0 5002391 0 00 110 Production Liner 8,770' 11,220psi 9-5/8" Casing Structural Brian Glasheen, Operations Engineer 323-536 / 323-572 Sr Pet Eng: 8,530psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 brian.glasheen@hilcorp.com 907-564-5277 N/A Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.30 19:14:35 - 09'00' Noel Nocas (4361) By Grace Christianson at 2:40 pm, Dec 01, 2023 Rig Start Date End Date 10/6/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 13-08 50-133-20304-00-00 177-029 10/06/2023- Friday 10/07/2023 - Saturday PJSM and PTW. Simops with production SS/LS/IA all 0psi. R/U YJ Eline, remove wellhouse for rig work MU gamma and 3.5" CIBP (2.75"OD) (CCL to plug 15') Stab on short string, Pressure test lubricator to 250psi/3000psi - Test good RIH, sat down in sliding sleeve at 2,457'. Consult slickline and found out the SS ID is 2.75". POOH and mobilize 2.5"OD plug from AK E-line. MU gamma and 2.875" CIBP (2.1"OD) (CCL to plug 15') Stab on long string, Pressure test lubricator to 250psi/3000psi - Test good RIH and pull correlation pass. Pull on depth and set CIBP at 5570' (plug 6ft into the 1st joint below the packer). PU, RIH and tag plug, good set. POOH. Stab on short string MU gamma and 3.5" CIBP (2.50"OD) (CCL to plug 9.0') RIH and pull correlation pass. Pull on depth and set CIBP at 5570' (plug 6ft into the 1st joint below the packer). PU, RIH and tag plug, good set. POOH. MU CCL and 3.5" jet cutter (2.5"OD) (CCL to cutter 2.5') RIH and pull correlation pass. Pull on depth and fire cutter at 5,550' (2ft above the packer). POOH, jet cutter fired. Swap to long string MU CCL and 2.875" jet cutter (2.063"OD) (CCL to cutter 2.5') RIH and pull correlation pass. Pull on depth and fire cutter at 5,550' (2ft above the packer). POOH, jet cutter fired. Secure well RD YJ Eline Level pad, install circulating flanges to tree while waiting for liner to be delivered. Lay felt & liner, spot base beam, spot carrier to well center. Spot aux eq. r/u circulating lines to pits & pump, raise & scope out mast, secure same, install burming, r/u crown light, SDFN 10/08/2023 - Sunday PTSM, PTW, Cont. hooking up rig eq. Power & circ lines. Line up to circulate well, Pump down SS, lined up to take returns out annulus, pumped 12 bbls filling tubing & pressured up t/1500psi, S/D pressure bled down t/500 psi in8 minutes, R/U gauge on LS, opened to monitor, pumped on SS & pressured up t/1600psi no communication to LS, R/U pump down LS monitor SS, pumped 19 bbls then pressured up LS t/1500 psi, no communication to SS, make several attempt to clear. Continue rigging up & prepping Eq, discuss options, decide to open Sliding sleeves @ 5513' LS, & 5480' in SS. R/U S/l, m/u 3 1/2" shifting tool, Stab on lubricator, test t/2000psi good, RIH make passes through sliding sleeve & locate make attempts to open with no joy, POOH to pick up brush, tool located in upper sleeve@ 2457'& opened, Circulated hole volume @ 3bpm, 150 psi, clean returns, Move S/L to L/S, RIH with shifting tool & brush. t/ locate sleeve @ 5513'', open sleeve, verify good. Circulate hole volume down long string @ 3.6 BPM, 740 psi. POOH w/ SL, f/ 2800', RIh w/ S/L with closing tool, verify upper sleeve closed after pulling through it. R/D S/L, Bundle Test Tubing & casing t/1500 psi, with no Joy. Secure well, SDFN. Pull on depth and set CIBP at 5570' (plug 6ft into the 1st joint below the packer). PU, RIH and tag plug, good set. POOH. closing tool, verify upper sleeve closed after pulling through it. R/D S/L, Bundle Test Tubing & casing t/1500 psi, with no Joy. Secure well, SDFN. Pull on depth and fire cutter at 5,550' (2ft above the packer). POOH, jet cutter fired. Secure well Pull on depth and fire cutter at 5,550' (2ft above the packer). POOH, jet cutter fired. Swap to long string Pull on depth and set CIBP at 5570' (plug 6ft into the 1st joint below the packer). PU, RIH and tag plug, good set. POOH. Rig Start Date End Date 10/6/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 13-08 50-133-20304-00-00 177-029 10/10/2023 - Tuesday Approve PTW and held PJSM. Warmed up equipment. Changed out door seal on upper ram. M/u 3-1/2" test joint and R/u testing eq. flood stack and shell tested 250-2000psi good test. Tested BOPE as per Sundry as following: Annular 250- 2000psi, Rams 250-2000psi, Valves 250-2000psi. Performed Accumulator Drawdown and tested gas detection. 1 fail/pass recorded on Kill Valve #2, cycled and greased valve and the sequential test was good. Test with 2-7/8" and 3- 1/2" test joint. AOGCC witness waived by Jim Regg on Mon 10/9/2023 10:04 AM. L/d testing eq. Pulled blanking subs and BPV's form LS and SS. Well static. R/u handling eq. M/u 3-1/2" landing jt to the LS. BOLDS. Pick up on LS (2-7/8" N-80 Tubing) hanger off seat at 15k worked pipe up to 80k (80%) pipe not free. Landed LS, R/u 3-1/2" landing joint on SS. Picked up on SS (3-1/2" N-80 Tbg) hanger came off seat at 25k worked pipe up to 105k pipe not free. ~5 of stretch at 105k. Call out for EL to make cut on LS and SS. L/d landing jt. secure well and SDFN. AK E-line will spot eq tonight and get ready to cut tbg tomorrow morning. 10/09/2023 - Monday PTSM, PTW, check well static. Install BPV'S, N/D tree. Prep Wellhead, install blanking subs, N/U BOPE, Install floor, r/u accumulator lines, Function test BOPE good. M/U 3 1/2" test joint, p/u handling Eq. fill stack had door leak on upper rams, investigate had damaged seal, locate seals getting mobed to beach. M/U 2 7/8" test joint, pull & l/d 3 1/2 test joint, work on housekeeping & finishing up stairs & landings. secure well, SDFN 10/11/2023 - Wednesday Approved PTW and held PJSM. Warmed up Eq. M/u landing joint to LS. Pulled hanger off seat at 15k. Picked up to 50k and set pipe in the slips. R/u AK E-line, M/u wt bars, centralizer, CCL and 2.06 jet cutter (2.8' offset from CCL). RIH correlated on depth. Fired cutter at 5544' ~3' above packer pup joint. POOH L/d tools confirmed cutter fired. Picked up on LS worked up to 80k pipe not free, continued working pipe while waiting on RCT from AK E-line to arrive. Set landing joint in slips with 30k over pulled into LS. Cutter on location, Built RCT and toolstring. RIH with RCT correlated on depth. Set anchor and fired cutter at 5543'. POOH confirmed cutter fired. Picked up on LS to 80k pipe not free. Continued working pipe up to 80k with no luck. M/u landing joint to SS. R/d circ eq. Pump down SS and return up IA to confirm SS was opened. R/d circ eq. Picked up and pulled 90k on SS and set slips. R/u EL, M/u wt bar CCL and 2.5" jet cutter for 3- 1/2" tbg. RIH on SS. Correlate on depth. Fired jet cutter 5542'. POOH L/d tools confirmed cutter fired. RD EL. Picked up on SS, worked up to 125k, could not work pipe free. Landed hanger and L/d landing joint. Secured well and SDFN. Rig Start Date End Date 10/6/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 13-08 50-133-20304-00-00 177-029 10/12/2023 - Thursday Held PJSM, discussed daily activities and approve PTW. Warmed eq. R/u circulating eq. Pumped lube pill down the LS and up the IA to 1000'. R/d circulating eq. MIRU Pollard SL. R/u on the LS, RIH with 2-7/8" BO shifting tool and closed sliding sleeve at 5513'. POOH. M/u 3-1/2" BO shifting tool. RIH on SS and closed sleeve at 2457'. POOH R/d SL. R/u circulated eq on LS. Lined up to take returns from IA valve. Pressured up on LS to 2500psi, pressure leaked off to 500psi in 1 min. Continue pressuring up on LS to 2500psi and surging tbg no luck. Picked up on LS to 30k over, began pressuring up on LS to 2500psi was able to break circulation. Worked rate up and CBU at 3.5bpm/1000psi. No change in returns at BU. Circulate an additional 60bbbls no change in returns. S/d. R/u circ eq. to the SS. Lined up returns to the IA. Pump online worked pressure up to 2100psi, pressure break catch returns circulated 30bbls at 3.5bpm/750psi. S/d pump. Picked up on SS worked pipe to 125k could not free pipe. Set BPV in LS, lined up to rev circulate up SS. Reversed circulated 2xbottoms up at 2.5bpm/1100psi. 1st bottoms no solids but fluid turns dirty. R/d circulating eq. Picked up on SS, worked pipe up to 125k (80%). No luck pulling free. 10/13/2023- Friday Held PJSM and approved PTW. Warmed eq. M/u landing joint to SS. R/u up power tong and HPU. Worked SS up to 125k with tq. No luck pulling free. MIRU AK E-line. M/u free point tool dressed for 3-1/2" tbg. RIH calibrate tool at 2000'. Worked Parmenter's with 90k pickup and 30k slack off. Began checking for free pipe in intervals. At 4600'=85% movement, 4687'=9% movement, 4752'=5% movement, 4800'=0%movment. POOH L/d tools. While waiting on EL to build the toolstring for jet cutter continued to picked up on the SS and worked up to 118k and the pipe came free. String wt @ 42k. Picked up with no drag and L/d the tbg hanger. R/d EL, secured well and SDFN. 10/14/2023 - Saturday Held PJSM and approved PTW. Warmed up Eq. Well well static. R/u tongs and prep floor to POOH. Spotted in pipe skate but could not reach the floor due to the elevation. R/u pipe skate on top of 40' float trailer. POOH with 3-1/2" IBT short string completion f/5,54' t/surface. Pumped pipe displacement every 15 jt. L/d 2 Sliding Sleeves, 21 pups, 176 joint and cut joint. Visual inspected pipe in good condition. M/u Landing joint to the LS. Picked up on LS to 65k and tbg pulled free. String wt @ 27k. Picked up string with no drag. R/u circulating eq. Reversed circulated at 3.5bpm/550psi, tbg plug off right before Bottoms Up. Swapped over the long way circulated 3bpm/400psi and cleared tbg. Swapped back to rev circulating 3.5bpm/550psi. Bottoms up returns chucky cement. Continued circulating until returns were clean. S/d pump. R/d circ eq. Pulled tbg hanger to rig floor and L/d same. PUW 27k. Secured well and SDFN. wt @ 42k. Picked up with no drag and L/d the tbg hanger. R/d EL, secured well and SDFN. Rig Start Date End Date 10/6/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 13-08 50-133-20304-00-00 177-029 10/15/2023 - Sunday Held PJSM and approve PTW. Warmed up eq. Check well static. POH L/d 2 joints of 3-1/2" Tbg and 3-1/2" x 2-7/8" OX sub. Swapped out handling equipment to pull 2-7/8" tbg. POOH L/d 2-7/8" N-80 Armco Seal-lok Tbg f/5543'. L/d 177 joints, 1 pup, 2 sliding sleeves, and the cut joint. Pipe was in fairly good condition only observed a few collars with minor pits. Filled hole every 15 joints outs with freshwater. Moved out pipe skate. R/d handling equipment, cleaned and cleared rig floor. MIRU pollard SL unit. M/u tool string RIH w/8.3" gauge ring/junk basket. Set down at 4120'slm. Could not work tool deeper. POOH, tool covered in pipe lube. M/u 3" bailer and RIH tagged at 5555'slm. POOH. Waited on 7.8" gauge ring. Crew cleaned cement debris from standpipe manifold. RIH w/7.9" gauge ring/junk basket and tagged at 5555'. POOH L/d tools. RDMO SL. Secured well and SDFN. 10/16/2023 - Monday Held PJSM and approved PTW. Warmed eq. Check well static. MIRU YJ E-line, M/u GR/CCL and baker setting tool and 7.71"OD CIBP for 9-5/8" Csg. RIH tool sticky at 5250', 5290' and 5450' tagged Tbg cut stumps at 5542'md. Picked up line stretch and set CIPB. Top of CIBP @ 5540'md. Tag plug and confirm set. Pulled gamma log to 5000' and POOH L/d setting tool and gamma. M/u Wt bar CCL and 3.625"OD Caliper Log Tool. RIH tagged CIBP and Logged 9-5/8" Cgs f/5525' t/surface. L/d tool sent data to yellow jacket analyst for review. Data will be emailed to OE. M/u wt bar CCL and 5"x40' dump bailer, mixed and loaded bailer with 38gals of cement. RIH and dumped on top of CIBP @ 5540'. POOH. RIH with same loaded with 38gals of cement. Dumped on top of plug. POOH, RDMO EL. Dumped 76gals=25' of cement. Estimate TOC at ~5515'md. RDMO EL, R/u testing eq. Fluid packed IA and MIT-IA to 1500psi, leaked off 100psi/min. R/d testing eq. Secured well and SDFN. 10/17/2023 - Tuesday R/u Testing eq. Shell test BOP's to 250-2000psi-good test. Tested BOPE as per Sundry: Annular 250-2000psi, Rams 250- 2000psi, Valves 250-2000psi. Performed Accumulator Drawdown Test. No failures. Gas detection was tested on 10/10/23. Tested with 2-7/8" and 5-1/2" Test Joint. Witness was waived by Jim Regg 10/16/2023 3:57 PM. R/d testing eq and blow lines dry. R/u handling eq. Rack tally 2-7/8" PH6 wk string. Strapped and Prepared 9-5/8" test packer. M/u 9- 5/8" J-3 Strom packer, RIH pickup 2-7/8" PH6 wk string t/240'. Shut down ops due a broken spring on the elevator door. Waited on elevators from Yellow Jacket. Cleaned and serviced rig and eq. Continued RIH with the 9-5/8" J-3 Strom Packer picking up 2-7/8" PH6 wk string f/240'. Spaced out and set packer at 4750'. Set 25k down. R/u testing eq. MIT-IA charted for 30mins. Initial=1666psi, 15mins=1661psi, 30mins=1659psi. Good test Bled off. R/u testing eq to Tbg. MIT-IA below packer at 4750'. Bled off ~100psi/min. R/d testing eq. Released packer, RIH picking up 2-7/8" PH6 wk string f/4750'. Spaced out and set packer 5100'md. Set 25k down. R/u testing eq. MIT-IA below packer at 5100'. Initial=1679psi, 15mins=1657psi, 30mins=1650psi. Good test Bled off. R/d test eq. Released packer, secured well and SDFN. TOC at ~5515'md. RDMO EL, R/u testing eq. Fluid packed IA and MIT-IA to 1500psi, leaked off 100psi/min. R/d testing Tool. RIH tagged CIBP and Logged 9-5/8" Cgs f/5525' t/surface. L/d tool sent data to yellow jacket analyst for review. Data will be emailed to OE. M/u wt bar CCL and 5"x40' TOC at ~5515'md. RDMO EL, R/u testing eq. Fluid packed IA and MIT-IA to 1500psi, leaked off 100psi/min. R/d testing stretch and set CIPB. Top of CIBP @ 5540'md. Tag plug and confirm set. Pulled gamma log to 5000' and POOH L/d setting iced rig and eq. Continued RIH with the 9-5/8" J-3 Strom Packer picking up 2-7/8" PH6 wk string f/240'. Spaced out and set packer at 4750'. Set 25k down. R/u testing eq. MIT-IA charted for 30mins. Initial=1666psi, 15mins=1661psi, 30mins=1659psi. Good test Bled off. R/u testing eq to Tbg. MIT-IA ug. POOH, RDMO EL. Dumped 76gals=25' of cement. Estimate charted for 30mins. Initial=1666psi, 15mins=1661psi, 30mins=1659psi. Good test Bled off. R/u testing eq to Tbg. MIT-IA below packer at 4750'. Bled off ~100psi/min. R/d testing eq. Released packer, RIH picking up 2-7/8" PH6 wk string f/4750'. Spaced out and set packer 5100'md. Set 25k down. R/u testing eq. MIT-IA below packer at 5100'. Initial=1679psi, 15mins=1657psi, 30mins=1650psi. Good test Bled off. R/d test eq. Released packer, secured well and stretch and set CIPB. Top of CIBP @ 5540'md. Tag plug and co dump bailer, mixed and loaded bailer with 38gals of cement. RIH and dumped on top of CIBP @ 5540'. POOH. RIH with Rig Start Date End Date 10/6/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 13-08 50-133-20304-00-00 177-029 10/18/2023 - Wednesday Held PJSM and approved PTW. Warmed eq. Check well static. R/d pipe skate. R/u matting boards and handing tools. POOH standing back 2-7/8" wk string. f/5100'. t/surface. L/d and inspected test packer all good. RIH with 2-7/8" wk string f/ derrick t/650'. SD ops. Derrickman SRL line got tangled up in the elevators. S/d job untangled and inspected line. PJSM, continued RIH t/5000' M/u 9-5/8" Storm Packer. RIH set Storm Packer @ 100'. Set packer, slacked off with 30k down on packer. Released running tool and POOH. 10/19/23 - Thursday Held PJSM and approved PTW, warmed eq. Cleared Rig Floor, N/d circ head from annular. R/d handrails and stairs. Pinned floor back to derrick. R/u lifting eq to stack and picked up with blocks,N/d tubing head spool, prep 9-5/8" csg stump. N/u new tbg head adapter. Test void 250-2500psi-good test. N/u BOP stack, N/u annular and installed 13-5/8" single gate (loaded with 7" rams) on top of double gate. N/u annular and circ head. R/u floor, handrails and stairs, Install test plug and shell test BOP stack 250L-2000psi-chart for 5mins good test. Pull test plug. M/u stinger RIH latched storm packer and released packer at 100'md. POOH L/d strom packer. Secured well and SDFN. 10/20/23 - Friday PJSM and PTW, warmed eq. Spot and R/u lay down machine and prep to L/d wk string, POOH L/d 156 joint of 2-7/8" PH6 wk string. Cleaned cleared rig floor, serviced loader, build 7" test joint, M/u 7" test joint. R/u testing eq. tested 7" ram 250-2000psi charted L/H for 5mins-good test. L/d Test jt and R/d testing eq. R/u some of parkers 7" handling eq. Racked and tally first row of 7". SDFN 10/21/23 - Saturday Held PJSM and approve PTW. Warmed up eq. Prep floor and handling eq for 7". Set parker HPU and hooked up hoses to single power tong. R/u BJ backup tongs. Racked and tally 7" 29# L-80 TXP casing joints. Put 9-5/8"x7" permanent hydraulic set isolation packer on pipe skate and m/u 10' pup on top. P/U packer, rig tong heads will not bite on 7-5/8'' xo. Switch power tongs and rig tongs position. Fighting positioning of tongs while torquing up, pup gets torqued up. Switch tongs back around. P/u joint of 7". Still fighting positioning of tongs. While torquing up, elevators are being pushed into the mast. Worried we will damage pipe, r/d parker and rig tongs, dress McCoys for 7'', R/U McCoys. RIh with packer assembly pickup 7" 29# L-80 TXP Csg Jts t/375. P/U and M/U second packer and conitued RIH picking up 7" TXP Csg Jt. f/375'-t/556'. S/O 14k. Secure well and SDFN 10/22/23 - Sunday Held PJSM and approve PTW. Warmed up eq. and service rig. Check well static. RIH picking up 7" 29# P-110 casing joints f/556' t/1023'. S/d to troubleshoot isuues with HPU. Swapped out HPU for tongs. Continue RIH picking up 7" 29# P-110 casing joints f/1023'md t/5122'md. Make up torque avg 14,000lb-ft. Build completion fliud in pits. PUW=108k, SOW=96. M/u Landing jt with TIW and casing hanger. Secure well SDFN Csg Jt. f/375'-t/556'. S/O 14k. Secure well and SDFN Rig Start Date End Date 10/6/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 13-08 50-133-20304-00-00 177-029 PTSM, Warm Eq., load skate w/4 1/2" completion,, P/U 4 1/2" Jewelry as per completions tally,- WLEG, joint 4 1/2" tubing, Pup, x-nipple, pup, 7 x 4 1/2" Perm Packer, pup, = 69', Cont RIH w/ 4 1/2" IBTM, 12.6# L-80 tubing, tag 7"x 4 1/2" xo @5102' DPM, up wt 51k, dn wt 40k,P/U & space out, M/U hanger & landing joint, land hanger, RILD pins, placing tubing tail @ 5051', R/U circulating lines, Rev circulate spotting 100bbls 1%KCL 1% corrosion inhibitor & 2 bbls diesel in IA, Drop bar let fall, pump down tubing pressure up t/3835psi to set packer @4982'-4987' hold for tubing test 30 min- initial 3835, 15 min 3815, 30 min 3805, good test. Pressure up IA t/1650 psi, hold 10 min good, Blow down lines. Secure well for night. 10/27/23 - Friday PTSM, Warm Eq. checked lines clear, prep to Test IA, R/U test IA t/1500 psi with AOGCC inspector Sully Sullivan, initial pressure 1780, 15 min 1775, 30 min 1775, good, R/U W/L RIH 4997' & pull ball & rod, rih pull RHCP, R/D w/l. Install TWC, R/D floor, N/D BOPE, m/t pits, r/d aux eq. N/U tree, test voidt/5k, test tree t/5k good, pull TWC, secure well. SDFN PTSM, warm Eq. Check well good. Prep to pressure test packoff from above, Test t/1625 psi f/ 10 min good, Combo Test 7" x 9 5/8" with 7", t/1500psi, no luck, Pressure up 7" t/4500psi hold for 30 min (re-attempt packer seting procedure at higher pressure). Attempt to test 7 x 9 5/8" t/ 1500 psi, with no joy, R/U wireline, RIH & retrieve prong from RHCP set @ 5110', Test lower packer @ 5097' from below t/1700psi f/30 min, good,RIH w/wireline, retrieve RHCP from x-nipple @ 5110', RIH w/ PX plug, set in xn nipple @ 5110', RIH w/ prong, set in PX plug @ 5110', R/U & test plug t/1650psi f/10 min good. R/D wireline. R/D stairs, hand rails & pin back floor. N/D BOPE, install tubing spool & test void t/4500psi 15 min good, N/U BOPE secure well for night. Rest Crew 10/25/23 - Wednesday PTSM, Warm & start Eq. Blow through surface lines good. Tq flanges on BOPE, install choke & kill lines, install floor, stairs & hand rails. Test Gas detection & PVT, Function test BOPE good, M/U 4 1/2" TJ w/test plug, land same. Fill surface lines. Test BOPE as per Hilcorp & AOGCC requirements, AOGCC witness was waived by Mr Regg via phone conversation 10-24- 23 @15:55, test 250/2000 with 4 1/2" TJ, R/D test Eq.,R/U W/L, Rih retrieve prong, Rih retrieve plug, R/D W/L, R/U to run 4 1/2" completion. Secure well for night. 10/26/23 - Thursday 10/23/23 - Monday Approve PTW and held PJSM. Warmed eq and serviced rig. Held PJSM and approve PTW. Warmed up equipment and Serviced rig, R/u circulating eq. lined up and rev cicrulated 130bbls of 1%KCL and 1% corrosion inhibtor down 7" x 9-5/8" annulas at 3pbm/100psi. R/d circ eq. R/u circulating eq. Lined up to rev circulate, pumped 130bbls of 1% KCL with 1% Corrosion Inhibitor down 7" x 9-5/8" annulas taking returns from 7" at 3bpm/100psi. S/d pump, B/o landing jt XO and dropped ball&rod. M/u Landing Jt XO. Pressured up on 7" to 3500psi to set packers, held for 30mins while charting-good test. Dropped ball and rod, Bled off test pressure. BO/LD landing joint. changed out handling eq to pick up 2-7/8" wk string, RIH w/2-7/8" 7.9# PH6 wk string 10/24/23 - Tuesday initial 3835, 15 min 3815, 30 min 3805, good test. Pressure up IA t/1650 psi, hold 10 min good, Blow down lines. Secure PTSM, Warm Eq. checked lines clear, prep to Test IA, R/U test IA t/1500 psi with AOGCC inspector Sully Sullivan, initial pressure 1780, 15 min 1775, 30 min 1775, good, R/U W/L RIH 4997' & pull ball & rod, rih pull RHCP, R/D w/l. Install TWC, PTSM, Warm Eq., load skate w/4 1/2" completion,, P/U 4 1/2" Jewelry as per completions tally,- WLEG, joint 4 1/2" tubing, Pup, x-nipple, pup, 7 x 4 1/2" Perm Packer, pup, = 69', Cont RIH w/ 4 1/2" IBTM, 12.6# L-80 tubing, tag 7"x 4 1/2" higher pressure). Attempt to test 7 x 9 5/8" t/ 1500 psi, with no joy, R/U wireline, RIH & retrieve prong from RHCP set @ 5110', Test lower packer @ 5097' from below t/1700psi f/30 min, good,RIH w/wireline, retrieve RHCP from x-nipple @ Rig Start Date End Date 10/6/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 13-08 50-133-20304-00-00 177-029 Move in and spot equipment, Rigging up coil tbg equipment, pick up injectior head, make up tools, CTC, X/O, stinger, X/O, 2.72 OD cmt nozzle, Pressure test BOP's & Lubricator to 250 low and 3500 psi high, Open well RH with 1-3/4 coil tbg. N2 on line at 1500 ft. CTM N2 on line at 1400 scfm, continue in hole jetting well dry in reverse, adjusting rates f/ 1600 scfm to 800 scfm, max well head pressure 2592 psi, tagged bottom 5509 ctm with 5k wt down no wash off. Pooh continue jetting well dry Recovered 110 bbls of water. At surface secure well, At surface, rig down injector Store injector on trailer rack,Rigging down secure well for night. 10/30/23 - Monday NIpple down BOPE, rig down & load out coil tbg equipment. 10/28/23 - Saturday PTSM, Load trailers, R/D office trailer, Prep carrier & scoope down mast, lay over same, secure lines & prep for travel, Load base beam & rest of aux eq. pull liner & felt, clean location, stage Misc. eq on middle pad & send rig items to yard for maint. 10/29/23 - Sunday 11/15/2023 - Wednesday YJEL arrive in field, PTW, PJSM, check in at the office. MIRU and pressure test lubricator 250L/1500H, good. RU Halliburton EPX log. Stab on well. RIH w/ TTTCu/XHU/PRC069/EPX/PRC34/BUL006 to 5050ft. Complete main logging run at 10fpm. Completed log. RMDO Halliburton and YJEL. 11/05/23 - Sunday Pull on depth and perforate Pool 6 C1 (5475-5495'). POOH, all shots fired, gun is dry. SITP 201psi, no change in 15 min Pull on depth and perforate Pool 6 C1 (5461-5481'). POOH, all shots fired, gun is dry. SITP 197psi, no change in 15 min Pull on depth and perforate Pool 6 C1 (5441-5461'). POOH, all shots fired, gun is dry. SITP 195psi, no change in 15 min Pull on depth and perforate Pool 6 C1 (5421-5441'). POOH, all shots fired, gun is dry. SITP 195psi, no change in 15 min Tyonek Isolation: Cement Retainer @ 8,245' Permanent Packer @ 8,250' KBU 13- 8 Pad 41-18 804' FNL, 685' FWL, Sec. 18, T4N, R11W, S.M. TD: 8,770' MD 7,664' TVD Perforations: Date Interval Condition Zone 11/5/23 5,421-5,595' Open Sterling Pool 6 8/11/77 4,820'-4,822' Sqz,d w/ 500 sks Sterling 8/11/77 5,058'-5,060' Sqz,d w/ 150 sks Upper Beluga 8/10/77 5,398'-5,400' Sqz,d w/ 500 sks Upper Beluga 8/10/77 5,658'-5,660' Sqz,d w/ 200 sks Upper Beluga 9/8/77 5,658'-5,694' Production Upper Beluga 9/9/77 5,752'-5,770' Production Upper Beluga 9/15/77 5,755'-5,765' Production Upper Beluga 9/10/77 5,804'-5,830' Sqz,d w/ 250 sks Upper Beluga 9/10/77 5,872'-5,912' Sqz,d w/ 250 sks Upper Beluga 9/15/77 6,005'-6,025' Production Upper Beluga 9/15/77 6,092'-6,098' Production Upper Beluga 9/14/77 6,142'-6,148' Production Upper Beluga 8/10/77 6,298'-6,300' Sqz,d w/ 200 sks Middle Beluga 8/24/77 6,344'-6,384' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,446'-6,458' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,466'-6,474' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,790'-6,804' Sqz,d w/ 600 sks Middle Beluga 9/5/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 9/6/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 8/25/77 6,820'-6,845' Sqz,d w/ 600 sks Middle Beluga 8/25/77 6,852'-6,882' Sqz,d w/ 600 sks Middle Beluga 8/25/77 7,004'-7,018' Sqz,d w/ 600 sks Middle Beluga 9/5/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 9/6/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 8/25/77 7,040'-7,076' Sqz,d w/ 400 sks Middle Beluga 8/25/77 7,244'-7,264' Sqz'd w/ 200 sks Middle Beluga 8/10/77 7,568'-7,570' Sqz,d w/ 150 sks Lower Beluga 8/20/77 7,578'-7,628' Production Lower Beluga 8/22/77 7,642'-7,662' Production Lower Beluga8/22/77 7,672'-7,680' Production Lower Beluga 8/22/77 7,776'-7,812' Production Lower Beluga8/21/77 7,840'-7,865' Production Lower Beluga 8/21/77 7,892'-7,916' Production Lower Beluga 8/21/77 8,202'-8,218' Production Lower Beluga 8/10/77 8,308'-8,310' Sqz,d w/ 150 sks Tyonek Surface Casing 13-3/8" 61 ppf K-55 Butt Top Bottom MD 0' 2,505' TVD 0' 2,276' 17-1/2" hole, cmt w/ 1,200 sks & 200 sks of Class G Conductor 20" 94 ppf 0.50" wall thickness Top Bottom MD 0' 114' TVD 0' 114' Production Casing 9-5/8" 47 ppf N-80 Butt Top Bottom MD 0' 8,770' TVD 0' 7,674' 12-1/4" hole cmt w/ 3,000 sks of Class G (and many remedial squeezes on rig) Depth 21' 4,715' 5,097' 5,109' 5,121' 5,540' Depth 21' 4,982' 4,997' 5,051' 5,540' Depth 5,551' to 5,564' 5,570' 5,596'5,662' to 5,722' 5,753' to 5,793' 5,986' to 6,046' 6,000' to 6,030'6,076' to 6,176' 6,207'6,241' to 6,250' 6,281' 7,428' 7,463' to 7,481'7,513' 7,546' Depth 5,553' to 5,564' 5,570' 5,594' Jewelry 7" Casing Casing Hanger 1. 9-5/8"x7" Perm Hydraulic Set Iso Pkr 2. 9-5/8"x7" Perm Hydraulic Set Iso Pkr 3. 4.5" Profile Nipple 4. WLEG 5. CIBP w 45' cmt - TOC @ 5,495' Jewelry 4-1/2" Tubing Casing Hanger A. 7"x4.5" Perm Hydraulic Set Iso Pkr B. 4.5" Profile Nipple C. WLEG D. CIBP w 45' cmt - TOC @ 5,495 Jewelry 2-7/8" Long String L1. Baker Dual Hydraulic Packer L2. CIBPL3. Otis "XA" sleeve L4. Baker Blast JointsL5. Baker Blast Joints L6. Baker Blast JointsL7. 1" ID Tubing Patch (installed 5/79) L8. Baker Blast Joints L9. Otis "XA" Sleeve L10. Baker Single Hydraulic packer L11. Otis "XA" SleeveL12. Otis "XA" Sleeve L13. Baker Model D Pkr w/Tbg Locator & Seal L14. Otis "X" Nipple L15. Bottom of Mule Shoe Jewelry 3-1/2" Short String S1. Baker Dual Hydraulic Packer S2. CIBPS3. Otis "XN" Nipple S1/L1 S3 3 L4 L5 L7 L8 L6 L3 L9 L10 L11 L12 L13 L14 L15 Permit #: 177-029 API #: 50-133-20304-00-S01 Prop. Des: A - 028142 KB elevation: 98' (21' AGL) Latitude: Longitude: Spud: 7/19/1977 04:00 hrs TD: 8/6/1997 Rig Released: 9/28/1977 12:00hrs PA #: 891006367C Beluga (both tubing strings are S01) Well Name & Number: Municipality: Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 13- 8 Kenai Peninsula Borough ~1.5º / 100' @ 394' 8/10/1977 D Ambruz Lease: State: Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 31º 17º RKB:98' (AMSL)21' (AGL) 11-16-23 PBTD: 8,245' MD 7,152' TVD Tubing 4-1/2'' 12.6 ppf L-80 Top Bottom MD 0' 5,051' TVD 0' 4,225' SCHEMATIC ToC in 9-5/8" x 12.25" OH 4650' (9/4/77 CBL after Cut 5,550' 10/06/23 Scab Liner 7" 29 ppf P-110 Top Bottom MD 0' 5,122' B L2 1 2 34 5/D A BC S3S3S2 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/30/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231130 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 11/13/2023 YELLOW JACKET GPT BCU 13 50133205250000 203138 10/5/2023 YELLOW JACKET PERF KBU 13-08 50133203040000 177029 10/16/2023 YELLOW JACKET CALIPER KU 12-17 50133205770000 208089 10/4/2023 YELLOW JACKET CALIPER/TEMP KU 24-7RD 50133203520100 205099 10/4/2023 YELLOW JACKET CALIPER MPU B-32 50029235700000 216151 9/20/2023 YELLOW JACKET RCT MPU L-47 50029235500000 215117 10/25/2023 YELLOW JACKET CUT NS-05 50029232440000 205009 9/9/2023 YELLOW JACKET PERF NS-16A 50029230960100 206141 9/12/2023 YELLOW JACKET PERF NS-20 50029231180000 202188 9/11/2023 YELLOW JACKET PERF NS-24 50029231110000 202164 9/10/2023 YELLOW JACKET PATCH PTM P1-13 50029223720000 193074 10/24/2023 YELLOW JACKET PL Please include current contact information if different from above. T38164 T38164 T38165 T38166 T38167 T38168 T38169 T38170 T38171 T38172 T38173 T38174 12/1/2023 YELLOW KBU 13-08 50133203040000 177029 10/16/2023 JACKET CALIPER Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 10:42:44 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 13-08 KENAI BELUGA UNIT 13-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2023 13-08 50-133-20304-00-00 177-029-0 N SPT 5000 1770290 1500 0 0 0 0 0 0 0 0 OTHER P Sully Sullivan 10/27/2023 MIT IA after cement plug per sundry #323-572 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KENAI BELUGA UNIT 13-08 Inspection Date: Tubing OA Packer Depth 0 1780 1775 1775IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS231105143437 BBL Pumped:0.5 BBL Returned:0.5 Wednesday, December 6, 2023 Page 1 of 1            1-Gas producer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Brian Glasheen Subject:RE: KBU 13-08 AOGCC 10-403 PTD 177-029 Submitted 09-29-23 - Sundry Application Date:Wednesday, October 25, 2023 9:45:00 AM Brian, The test of the 7” casing against the 9-5/8” CIBP verifies integrity of the 7” casing and isolation from the proposed Pool 6 perfs and the 9-5/8” x 7” annulus. There is no evidence of sustained casing pressure inside the 9-5/8” casing over the prior year. This well will be operable as a producer, on the following condition: 1. The 7” x 4-1/2” MITIA to 1500 psi passes. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Tuesday, October 24, 2023 4:22 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: KBU 13-08 AOGCC 10-403 PTD 177-029 Submitted 09-29-23 - Sundry Application Bryan, Per conversation over the phone. Hilcorp would like to waive the pressure test on the 9-5/8’’ X 7” annulus in step 40 of the program attached. The new annulus will act as the OA. Pressure test of the above packer is attached. Also attached is the pressure test of the lower packer showing a good test. Currently we have 7’’ casing in the ground that has passed a MIT against the 9-5/8’’ CIBP with cement to ~1600psi (Chart above). Plan forward would be to run the 4-1/2’’ tubing and perform a MIT-T and MIT-IA proving two barriers . Thanks Brian Glasheen Ops Engineer 907-545-1144 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: * N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,770 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 4,760psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng brian.glasheen@hilcorp.com 907-564-5277 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: SS 3-1/2" PRESENT WELL CONDITION SUMMARY Brian Glasheen, Operations Engineer AOGCC USE ONLY Bryan McLellan October 18, 2023 Tubing Grade: 9.2# / N-80 Tubing MD (ft): 5,595Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 177-029 50-133-20304-00-00 Hilcorp Alaska, LLC Proposed Pools: 6.4# / N-80 TVD Burst 4,686' 6,870psi 2,276' Size 114' 2,505' MD See Attached Schematic 3,090psi 114'114' 2,505' October 18, 2023 LS 2-7/8" 8,770' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 13-08CO 510C Sterling Gas Pool 6 7,674'9-5/8" ~800 psi 8,770' 8,245' Length See Schematic; N/A See Schematic; N/A 7,664 8,245 7,152 Kenai Beluga-Up Tyonek Gas 20" 13-3/8" See Attached Schematic m n P s 66 t N *Convert to Gas Storage Production Well Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:40 pm, Oct 19, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.10.19 10:56:14 - 08'00' Noel Nocas (4361) 323-572 October 18, 2023 Storage Pool Reporting Code is 448809 Verbal approval was provided on 10/18/23 SFD SFDFEDA022330, Sterling 6 Gas Storage Provide AOGCC opportunity to witness MITIA to 1500 psi (7" x 4-1/2" annulus) CT BOP test to 2000 psi Well shall be used only for production from the gas storage pool unless the requirements of SIO 7A and 20 AAC 25.252 are met. BOP test to 2000 psi BJM 10/24/23 10-404 DSR-10/19/23SFD 10/20/2023 Perforate New Pool P Yes X SFD *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.24 13:59:59 -08'00'10/24/23 RBDMS JSB 102623 Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Well Name: KBU 13-08 API Number: 501332030400 Current Status: SI gas well Permit to Drill Number: 177029 Estimated Start Date: 10/05/23 Rig: 401 workover rig, Eline First Call Engineer: Brian Glasheen 9075451144 Second Call Engineer: Chad Helgeson (907) 229-4824 (C) AFE Number: Job Type:Uphole recomplete Current Bottom Hole Pressure: 1335 psi @ 5356’ TVD (Offset KBU 11-17X 5 ppg EMW) Maximum Expected BHP: 1335 psi @ 5356’ TVD (New perfs being added but lower pressure pool 6 ~ 245 psi) MPSP: 800 psi (0.1 psi/ft gas gradient) Brief Well Summary: KBU 13-08 was drilled and completed 1977. Multiple perfs were added and straddle via packers with one short string and one long string with sliding sleeve for selective production in the beluga pool. Well has been SI since 2006. Notes Regarding Wellbore Condition x 9 -5/8’’ TOC ~4650 per CBL 9-4-77 post squeezes x SL drifted 5559’ SLM with 2.7’’ gauge ring on the short string x SL drifted 5609’ SLM with 2.25’ gauge ring on the long string Objective: The purpose of this work is to plug back the Beluga Pool, decomplete the dual string completion, install 5.5’’ tubing and complete the well as a pool 6 storage well to help meet peak demand gas rates throughout the winter. Hilcorp requests a variance to 20 AAC 25.112 (c)(1)(E) for placing cement within 106 ft of the top perf. There is one packer (5551’) between the top perfs and proposed bottom of cement. This procedure proposes packer to be equivalent to a mechanical bridge plug. This procedure includes the steps to place a CIBP and cement as close to the packer as possible in the casing to meet 20 AAC 25.112 (c)(1) where the hydrocarbons are confined to their indigenous strata and will not migrate to surface, but they will greater than 100ft of the top of perforations, as required in the regulations. Top’s :Beluga/Upper Tyonek pool is defined from KU 41-18 and Pool 6 and Pool 5.2 are defined by KU 21-06 Top Kenai Beluga/Upper Tyonek Gas Pool: 5633’ MD, 4718’ TVD Top Pool 6: 5389’ MD, 4509’ TVD Top Pool 5.2: 5057’ MD, 4230’ TVD Eline: ( Note this is pre rig work and not the reservoir P&A) 1. RU to short string. Test lubricator to 250/3,000 psi. 2.RIH and set 3.5’’ CIBP at ~ 5570’ (just below packer in first full size joint) 3. Jet cut tubing 1-2’ above packer at ~5549’ MD 4. RU to Long string. Test lubricator to 250/3,000 psi. d complete the well as a pool 6 storage well to help meet peak demand gas rates throughout the winter. Approved as a producer only. -bjm Variance approved. -bjm Uphole recomplete Well: KBU 13-08 Date: 09/21/23 5. RIH and set 2-7/8’’ CIBP at ~ 5570’ (6’ below packer inside first full joint of 2-7/8’’ ) 6. Jet cut tubing 1-2’ above packer at ~5549’ MD 7. CMIT-T (SS and LS) x IA to 1500 psi. Confirm CIBP are holding and casing integrity. (If fails a test packer run will be performed during the RWO) Pre-Rig Procedure: 8. Circulate at least one wellbore volume through both the SS an LS with 8.5 ppg KCL/ Produced water down tubing, taking returns up casing. Brief RWO Procedure: 9. MIRU 401 WO Rig, ancillary equipment, and lines. 10. Set BPV in SS and LS. ND Tree. NU BOPE 11. Provide AOGCC 24 hrs in advance of BOP test 12. Test to 2000 psi with 2-7/8’’ and 3-1/2’’ test joints 13. Bleed any pressure off tubing and casing. Pull BPV. Kill well as needed. 14. MU landing joint or spear and BOLDS. 15. PU on the LS tubing hanger. 16. Recover the tubing hanger. 17. POOH and lay down the 2-7/8” tubing. a. Tubing will be inspected. 18. PU on the SS tubing hanger. 19. Recover the tubing hanger. 20. POOH and lay down the 3-1/2” tubing. a. Tubing will be inspected. 21. RU ELINE 22. RIH with gauge ring to drift for 9-5/8’’ CIPB 23. RIH and set 9-5/8’’ CIBP just above cut tubing at 5549’MD 24. RIH and dump 25’ of cement on top of CIBP for res P&A. 25. RDMO ELINE 26. If pre rig CMIT after CIBP’s were set with Eline failed: a. RIH with 9-5/8’’ test/storm packer and set at 4750’MD b. Pressure test 9-5/8’’ to 1500 psi c. POOH and set at 100’ for wellhead CO 27. If CMIT after CIBP were set with Eline passed: a. RIH with 9-5/8’’ test/storm packer and set at 100’MD b. Pressure test to 500 psi 28. ND BOP, ND wellhead, Install new wellhead, Pressure test wellhead void, NU BOP, set test plug and test BOP’s. 29. RIH and pull 9-5/8’’ test/storm packer 30. Change out handling equipment, install casing crew tongs, and upper rams for handling 7” casing. 31. Perform BOP test on the 7” pipe rams on 7” test joint. 32. PU new 7’’ completion and RIH Ran a caliper log across 9-5/8" casing and it showed some almost complete penetrations, which prompted a change to the procedure to run a 7" tieback for long-term integrity. -bjm This is the point when the change to approved program was requested. -bjm Below the line is the subject of this change sundry. -bjm Test passed. -bjm Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Material Notes 4-1/2'' 1 WLEG/ Mule shoe L-80 4-1/2'' 3' 4 1/2'' X Nip with RHC L-80 4-1/2'' 10' Pup Joint L-80 7'' 5' XO L-80 7'' 10' Pup Joint L-80 7'' 9”-5/8 X 7” Packer L-80 Tri point packer ~Set ~5100' MD 7'' 6' Pup Joint L-80 7'' Joints L-80 7'' 4' Pup Joint L-80 7'' 9”-5/8 X 7” Packer L-80 Tri point packer ~Set ~4750' MD 7'' 6' Pup Joint L-80 7'' Joints L-80 7'' Space out PUPS L-80 7'' 1 joint L-80 7'' PUP L-80 7'' Tubing Hanger L-80 33. Space out and land the hanger. 34. Note PU (Pick Up) and SO (Slack Off) weights on tally. 35. RILDS. Lay down landing joint. 36. Pump 250 bbls of 1% KCL with 1% by volume Corrosion inhibitor down the IA. Taking returns up TBG. 37. Pump an additional 5 bbls of diesel freeze protect down the IA. (WSL discretion) 38. Swap to pumping down the 7’’. 39. Drop ball and rod and complete loading tubing and hydraulically set the packer as per Vendor setting procedure. 40. Pressure up and test the 7’’ Casing to 1500 psi for MIT-T. Bleed off the 7’’. Test the 9-5/8’’ annulus to 1500 psi. Record and notate all pressure tests (30 minutes) on chart. 41. RU SL Remove ball and rod and RHC 42. SL RIH and set TTP in X nip below 5100’ packer for isolation to install new wellhead. 43. ND BOP, Install new wellhead, Pressure test wellhead void, NU BOP, set test plug and test BOP’s. 44. Change out handling equipment, install casing crew tongs, and upper rams for handling 4-1/2” Tubing. 45. Perform BOP test with 4-1/2’’ test joint. Uphole recomplete Well: KBU 13-08 Date: 09/21/23 46. SL pull TTP from X nip 47. PU new 4-1/2’’ completion and RIH Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Material Notes 4-1/2'' 1 WLEG/ Mule shoe L-80 4-1/2'' 3' 4 1/2'' X Nip with RHC L-80 4-1/2'' 10' Pup Joint L-80 4-1/2'' 30 1 joint L-80 4-1/2'' 10' Pup Joint L-80 4-1/2'' 7”X4-1/2'' Packer L-80 Tri point packer ~Set ~5000' MD 4-1/2'' 6' Pup Joint L-80 4-1/2'' Joints L-80 4-1/2'' Space out PUPS L-80 4-1/2'' 1 joint L-80 4-1/2'' PUP L-80 4-1/2'' Tubing Hanger L-80 48. Space out and land the hanger. 49. Note PU (Pick Up) and SO (Slack Off) weights on tally. 50. RILDS. Lay down landing joint. 51. Pump 100 bbls of 1% KCL with 1% by volume Corrosion inhibitor down the IA. Taking returns up TBG. 52. Pump an additional 5 bbls of diesel freeze protect down the IA. (WSL discretion) 53. Swap to pumping down the 4-1/2’’ tubing. 54. Drop ball and rod and complete loading tubing and hydraulically set the packer as per Vendor setting procedure. 55. Pressure up and test the 4-1/2’’ tubing to 1500 psi for MIT-T. Bleed off the 4-1/2’’ tubing. Test the 7’’ annulus to 1500 psi. Record and notate all pressure tests (30 minutes) on chart. 56. ND BOP, NU tree and test 57. RDMO Rig 401. Provide AOGCC opportunity to witness MIT-IA. -bjm Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Post-Rig Procedure: Slickline: 1. RU Slickline. Test lubricator to 250/2,000 psi. 2. Pull ball and rod and RHC 3. RDMO Coil: 1. RU Coil. Test lubricator to 250/3,000 psi. 2. RIH and tag TOC. Stack as much weight as possible on cement to verify integrity. 3. Swap well over to N2. Reverse lift fluid from well. 4. RDMO Eline: 1. RU Eline. Test lubricator to 250/2,000 psi. 2. RIH and verify TOC via tag. Confirm 25’ of cement. If needed dump more cement to reach 25’ of cement. 3. Perforate the below sands in pool 6 from the bottom up: 4. Pool Sand Top MD Btm. MD Feet Pool 6 Pool 6 C1 5,421 5,501 80 5. RDMO Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Rig BOPE 401 Diagram 4. Existing Tree/Wellhead 5. Proposed Tree/Wellhead 6. Coil BOP Diagram 7. Nitrogen SOP 8. Blank RWO Changes Form Tyonek Isolation: Cement Retainer @ 8,245' Permanent Packer @ 8,250' KBU 13- 8 Pad 41-18 804' FNL, 685' FWL, Sec. 18, T4N, R11W, S.M. TD: 8,770' MD 7,664' TVD Perforations: Date Interval Condition Zone 8/11/77 4,820'-4,822' Sqz,d w/ 500 sks Sterling 8/11/77 5,058'-5,060' Sqz,d w/ 150 sks Upper Beluga 8/10/77 5,398'-5,400' Sqz,d w/ 500 sks Upper Beluga 8/10/77 5,658'-5,660' Sqz,d w/ 200 sks Upper Beluga 9/8/77 5,658'-5,694' Production Upper Beluga 9/9/77 5,752'-5,770' Production Upper Beluga 9/15/77 5,755'-5,765' Production Upper Beluga 9/10/77 5,804'-5,830' Sqz,d w/ 250 sks Upper Beluga 9/10/77 5,872'-5,912' Sqz,d w/ 250 sks Upper Beluga 9/15/77 6,005'-6,025' Production Upper Beluga 9/15/77 6,092'-6,098' Production Upper Beluga 9/14/77 6,142'-6,148' Production Upper Beluga 8/10/77 6,298'-6,300' Sqz,d w/ 200 sks Middle Beluga 8/24/77 6,344'-6,384' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,446'-6,458' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,466'-6,474' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,790'-6,804' Sqz,d w/ 600 sks Middle Beluga 9/5/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 9/6/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 8/25/77 6,820'-6,845' Sqz,d w/ 600 sks Middle Beluga 8/25/77 6,852'-6,882' Sqz,d w/ 600 sks Middle Beluga 8/25/77 7,004'-7,018' Sqz,d w/ 600 sks Middle Beluga 9/5/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 9/6/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 8/25/77 7,040'-7,076' Sqz,d w/ 400 sks Middle Beluga 8/25/77 7,244'-7,264' Sqz'd w/ 200 sks Middle Beluga 8/10/77 7,568'-7,570' Sqz,d w/ 150 sks Lower Beluga 8/20/77 7,578'-7,628' Production Lower Beluga 8/22/77 7,642'-7,662' Production Lower Beluga 8/22/77 7,672'-7,680' Production Lower Beluga 8/22/77 7,776'-7,812' Production Lower Beluga 8/21/77 7,840'-7,865' Production Lower Beluga 8/21/77 7,892'-7,916' Production Lower Beluga 8/21/77 8,202'-8,218' Production Lower Beluga 8/10/77 8,308'-8,310' Sqz,d w/ 150 sks Tyonek 8/18/77 8,334'-8,364' Isolated Tyonek 8/18/77 8,660'-8,680' Isolated Tyonek Surface Casing 13-3/8" 61 ppf K-55 Butt Top Bottom MD 0' 2,505' TVD 0' 2,276' 17-1/2" hole, cmt w/ 1,200 sks & 200 sks of Class G Conductor 20" 94 ppf 0.50" wall thickness Top Bottom MD 0' 114' TVD 0' 114' Production Casing 9-5/8" 47 ppf N-80 Butt Top Bottom MD 0' 8,770' TVD 0' 7,674' 12-1/4" hole cmt w/ 3,000 sks of Class G (and many remedial squeezes on rig) Depth 12' 73' 2,530' 5,513' 5,551' to 5,564'5,596' 5,662' to 5,722' 5,753' to 5,793'5,986' to 6,046' 6,000' to 6,030' 6,076' to 6,176' 6,207'6,241' to 6,250' 6,281' 7,428' 7,463' to 7,481' 7,513' 7,546' Depth 12' 2,457'5,480' 5,553' to 5,564' 5,594' Jewelry 2-7/8" Long String Cameron Split Hanger 1. 3-1/2" x 2-7/8" Crossover 2. Otis "XA" sleeve3. Otis "XA" sleeve 4. Baker Dual Hydraulic Packer 5. Otis "XA" sleeve 6. Baker Blast Joints7. Baker Blast Joints 8. Baker Blast Joints 9. 1" ID Tubing Patch (installed 5/79)10. Baker Blast Joints 11. Otis "XA" Sleeve 12. Baker Single Hydraulic packer 13. Otis "XA" Sleeve14. Otis "XA" Sleeve 15. Baker Model D Pkr w/Tbg Locator & Seal16. Otis "X" Nipple 17. Bottom of Mule Shoe Jewelry 3-1/2" Short String Cameron Split Hanger A. Otis "XA" SleeveB. Otis "XA" Sleeve C. Baker Dual Hydraulic Packer D. Otis "XN" Nipple 2A B C, 4 D 3 6 7 9 10 8 5 1 11 12 13 14 15 16 17 Permit #: 177-029 API #: 50-133-20304-00-S01 Prop. Des: A - 028142 KB elevation: 98' (21' AGL) Latitude: Longitude: Spud: 7/19/1977 04:00 hrs TD: 8/6/1997 Rig Released: 9/28/1977 12:00hrs PA #: 891006367C Beluga (both tubing strings are S01) Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 13- 8 Kenai Peninsula Borough 5,658' - 8,218' ~1.5º / 100' @ 394' 8/10/1977 Ryan Rupert Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 4,740' - 7,127' 31º ĺ 17º RKB:98' (AMSL)21' (AGL) 8/31/2020 PBTD: 8,245' MD 7,152' TVD Short String Tubing 3-1/2" 9.2 ppf N-80 Butt Top Bottom MD 0' 5,595' TVD 0' 4,686' Long String Tubing 2-7/8" 6.4 ppf N-80 Armco Seal-lok Top Bottom MD 0' 7,546' TVD 0' 6,487' SCHEMATIC ToC in 9-5/8" x 12.25" OH 4650'(9/4/77 CBL after squeezes) Tubing strings already removed at time of sundry application. -bjm Tyonek Isolation: Cement Retainer @ 8,245' Permanent Packer @ 8,250' KBU 13- 8 Pad 41-18 804' FNL, 685' FWL, Sec. 18, T4N, R11W, S.M. TD: 8,770' MD 7,664' TVD Perforations: Date Interval Condition Zone Proposed ±5,421-5,501' TBD Pool 6 8/11/77 4,820'-4,822' Sqz,d w/ 500 sks Sterling 8/11/77 5,058'-5,060' Sqz,d w/ 150 sks Upper Beluga 8/10/77 5,398'-5,400' Sqz,d w/ 500 sks Upper Beluga 8/10/77 5,658'-5,660' Sqz,d w/ 200 sks Upper Beluga 9/8/77 5,658'-5,694' Production Upper Beluga 9/9/77 5,752'-5,770' Production Upper Beluga 9/15/77 5,755'-5,765' Production Upper Beluga 9/10/77 5,804'-5,830' Sqz,d w/ 250 sks Upper Beluga 9/10/77 5,872'-5,912' Sqz,d w/ 250 sks Upper Beluga 9/15/77 6,005'-6,025' Production Upper Beluga 9/15/77 6,092'-6,098' Production Upper Beluga 9/14/77 6,142'-6,148' Production Upper Beluga 8/10/77 6,298'-6,300' Sqz,d w/ 200 sks Middle Beluga 8/24/77 6,344'-6,384' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,446'-6,458' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,466'-6,474' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,790'-6,804' Sqz,d w/ 600 sks Middle Beluga 9/5/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 9/6/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 8/25/77 6,820'-6,845' Sqz,d w/ 600 sks Middle Beluga 8/25/77 6,852'-6,882' Sqz,d w/ 600 sks Middle Beluga 8/25/77 7,004'-7,018' Sqz,d w/ 600 sks Middle Beluga 9/5/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 9/6/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 8/25/77 7,040'-7,076' Sqz,d w/ 400 sks Middle Beluga 8/25/77 7,244'-7,264' Sqz'd w/ 200 sks Middle Beluga 8/10/77 7,568'-7,570' Sqz,d w/ 150 sks Lower Beluga 8/20/77 7,578'-7,628' Production Lower Beluga 8/22/77 7,642'-7,662' Production Lower Beluga8/22/77 7,672'-7,680' Production Lower Beluga 8/22/77 7,776'-7,812' Production Lower Beluga8/21/77 7,840'-7,865' Production Lower Beluga 8/21/77 7,892'-7,916' Production Lower Beluga8/21/77 8,202'-8,218' Production Lower Beluga 8/10/77 8,308'-8,310' Sqz,d w/ 150 sks Tyonek Surface Casing 13-3/8" 61 ppf K-55 Butt Top Bottom MD 0' 2,505' TVD 0' 2,276' 17-1/2" hole, cmt w/ 1,200 sks & 200 sks of Class G Conductor 20" 94 ppf 0.50" wall thickness Top Bottom MD 0' 114' TVD 0' 114' Production Casing 9-5/8" 47 ppf N-80 Butt Top Bottom MD 0' 8,770' TVD 0' 7,674' 12-1/4" hole cmt w/ 3,000 sks of Class G (and many remedial squeezes on rig) Depth 12' 73' 2,530' 5,513' 5,551' to 5,564' 5,596' 5,662' to 5,722' 5,753' to 5,793' 5,986' to 6,046' 6,000' to 6,030' 6,076' to 6,176' 6,207'6,241' to 6,250' 6,281'7,428' 7,463' to 7,481'7,513' 7,546' Depth 12' 2,457'5,480' 5,553' to 5,564'5,594' Jewelry 2-7/8" Long String Cameron Split Hanger1. 3-1/2" x 2-7/8" Crossover 2. Otis "XA" sleeve3. Otis "XA" sleeve 4. Baker Dual Hydraulic Packer 5. Otis "XA" sleeve 6. Baker Blast Joints7. Baker Blast Joints 8. Baker Blast Joints9. 1" ID Tubing Patch (installed 5/79)10. Baker Blast Joints 11. Otis "XA" Sleeve12. Baker Single Hydraulic packer 13. Otis "XA" Sleeve14. Otis "XA" Sleeve 15. Baker Model D Pkr w/Tbg Locator & Seal16. Otis "X" Nipple 17. Bottom of Mule Shoe Jewelry 3-1/2" Short String Cameron Split Hanger A. Otis "XA" SleeveB. Otis "XA" Sleeve C. Baker Dual Hydraulic PackerD. Otis "XN" Nipple 2A B C, 4 D 3 6 7 9 10 8 5 1 11 12 13 14 15 16 17 Permit #: 177-029 API #: 50-133-20304-00-S01 Prop. Des: A - 028142 KB elevation: 98' (21' AGL) Latitude: Longitude: Spud: 7/19/1977 04:00 hrs TD: 8/6/1997 Rig Released: 9/28/1977 12:00hrs PA #: 891006367C Beluga (both tubing strings are S01) Well Name & Number: Municipality: Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 13- 8 Kenai Peninsula Borough ~1.5º / 100' @ 394' 8/10/1977 D Ambruz Lease: State: Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 31º ĺ 17º RKB:98' (AMSL)21' (AGL) 9/28/23 PBTD: 8,245' MD 7,152' TVD Tubing 4-1/2''" Top Bottom MD 0' ~ 5100' PROPOSED DRAFT ToC in 9-5/8" x 12.25" OH 4650'(9/4/77 CBL after squeezes) CIBP @ ±5549' MD w/ ~25' cement CIBP @ ±5570CIBP @ ±5559' Cut ~5549' 9-5/8''X7'' Packer ~4750 and ~5100' 7'' X 4.5'' Packer ~5000' Casing 7" Top Bottom MD 0' ~ 5160' Kenai Gas Field KBU 13-08 BOP Rig 401 9/28/2023 Choke and Kill valves 2 1/16 5M Mud Cross 4-1/16" 5M EFO Schrader 13 5/8-5000 Shaffer SL 2 7/8-5 ½’’ variables Blind 2-7/8” -5-1/2” variables and/or 7” pipe rams Kenai Gas Field KBU 13-08 Current 09/21/2023 Tree, block, dual, Cameron type F, 11 5M X 3 1/8 5M X 3 1/8 5M, EE trim, 5 3/64 centers, single master swab, 3 1/8 5M SSO 3 1/8 5M 5 bolt segmented top Tubing hanger, Dual, CIW- DCB, 11 X 3 1/2 EUE lift X 3 ½ IBT susp, w/ 3'’ type H BPV profile, 5 3/64 centers Kenai Gas Field KBU 13-08 20 X13 3/8 x 9 5/8 x 3 1/2 x 2 7/8 Tubing head, CIW-DCB, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, X bottom prep Casing spool, OCT-22-BP, 21 ¼ 2M X 13 5/8 5M, w/ 2- 2 1/16 5M SSO, OO bottom prep Casing head, OCT-22, 21 ¼ 2M X SOW, w/ 2- 2'’ LPO 20'’ 13 3/8'’ 9 5/8'’ 2 7/8'’3 ½’’ Tubing head, OCT-TC-00, 13 5/8 5M X 11 5M, w/ 2- 2 1/16 5M EFO Same AnnulusDSA, 13 5/8 3M x 11 5M Kenai Gas Field KBU 13-08 Proposed 10/18/2023 Casing spool, OCT-22-BP, 21 ¼ 2M X 13 5/8 5M, w/ 2- 2 1/16 5M SSO, OO bottom prep Casing head, OCT-22, 21 ¼ 2M X SOW, w/ 2- 2'’ LPO 20'’ 13 3/8'’ 9 5/8'’ 4 ½’’ Tubing head,Cactus-HPS, 13 5/8 5M x 11 5M, w/ 2- 2 1/16 5M SSO Tubing head, Cactus-HPS, 11 5M x 11 5M, w/ 2- 2 1/16 5M SSO Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim BHTA, Otis, 4 1/16 5M FE x 6.5'’ Otis quick union top Kenai Gas Field KBU 13-08 20 x 13 3/8 x 9 5/8 x 7 x 4 ½ Tubing hanger, Cactus-EN- CCL, 11 x 4 ½ EUE 8rd lift and susp, w/ 4'’ type H-BPV profile, 2- ¼npt control line port, 6 ¼ EN Adapter, Cactus-CCL, 11 5M stdd x 4 1/16 5M, w/ 2- 1'’ npt control line exits Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, EE trim 7'’ Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d R i g W o r k O v e r S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l K B U 1 3 - 0 8 ( P T D 1 7 7 - 0 2 9 ) Su n d r y # : X X X - X X X An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a te d t o t h e AO G C C by t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . Se c Pa g e Da t e Pr o c e d u r e C h a n g e Ne w 4 0 3 Re q u i r e d ? Y / N HA K Pr e p a r e d By (I n i t i a l s ) HA K Ap p r o v e d By (I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : A s s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : F i r s t C a l l O p e r a t i o n s E n g i n e e r D a t e CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Brian Glasheen Subject:RE: KBU 13-08 AOGCC 10-403 PTD 177-029 Submitted 09-29-23 - Sundry Application Date:Wednesday, October 18, 2023 3:14:00 PM Brian, Hilcorp has approval to proceed with the plan as outlined in the revised procedure and diagram. Follow up with a sundry for Change of approved Permit within 3 days. Also, please send the caliper log data and include it with the 10-404. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Wednesday, October 18, 2023 12:46 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: KBU 13-08 AOGCC 10-403 PTD 177-029 Submitted 09-29-23 - Sundry Application Bryan, Here is the revised program to be extra cautious with the anomaly observed in the caliper. The caliper noted possible holes above 1500’, however a casing test passed to above 1500 psi. Hilcorp would like to add an additional barrier as this will be a long-term storage well to meet the future gas demand. I will call to discuss the program revisions and look for your approval to move forward. Thanks Brian Glasheen Ops Engineer 907-545-1144 Tyonek Isolation: Cement Retainer @ 8,245' Permanent Packer @ 8,250' KBU 13- 8 Pad 41-18 804' FNL, 685' FWL, Sec. 18, T4N, R11W, S.M. TD: 8,770' MD 7,664' TVD Perforations: Date Interval Condition Zone Proposed ±5,421-5,501' TBD Pool 6 8/11/77 4,820'-4,822' Sqz,d w/ 500 sks Sterling 8/11/77 5,058'-5,060' Sqz,d w/ 150 sks Upper Beluga 8/10/77 5,398'-5,400' Sqz,d w/ 500 sks Upper Beluga 8/10/77 5,658'-5,660' Sqz,d w/ 200 sks Upper Beluga 9/8/77 5,658'-5,694' Production Upper Beluga 9/9/77 5,752'-5,770' Production Upper Beluga 9/15/77 5,755'-5,765' Production Upper Beluga 9/10/77 5,804'-5,830' Sqz,d w/ 250 sks Upper Beluga 9/10/77 5,872'-5,912' Sqz,d w/ 250 sks Upper Beluga 9/15/77 6,005'-6,025' Production Upper Beluga 9/15/77 6,092'-6,098' Production Upper Beluga 9/14/77 6,142'-6,148' Production Upper Beluga 8/10/77 6,298'-6,300' Sqz,d w/ 200 sks Middle Beluga 8/24/77 6,344'-6,384' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,446'-6,458' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,466'-6,474' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,790'-6,804' Sqz,d w/ 600 sks Middle Beluga 9/5/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 9/6/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 8/25/77 6,820'-6,845' Sqz,d w/ 600 sks Middle Beluga 8/25/77 6,852'-6,882' Sqz,d w/ 600 sks Middle Beluga 8/25/77 7,004'-7,018' Sqz,d w/ 600 sks Middle Beluga 9/5/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 9/6/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 8/25/77 7,040'-7,076' Sqz,d w/ 400 sks Middle Beluga 8/25/77 7,244'-7,264' Sqz'd w/ 200 sks Middle Beluga 8/10/77 7,568'-7,570' Sqz,d w/ 150 sks Lower Beluga 8/20/77 7,578'-7,628' Production Lower Beluga 8/22/77 7,642'-7,662' Production Lower Beluga 8/22/77 7,672'-7,680' Production Lower Beluga 8/22/77 7,776'-7,812' Production Lower Beluga 8/21/77 7,840'-7,865' Production Lower Beluga 8/21/77 7,892'-7,916' Production Lower Beluga 8/21/77 8,202'-8,218' Production Lower Beluga 8/10/77 8,308'-8,310' Sqz,d w/ 150 sks Tyonek Surface Casing 13-3/8" 61 ppf K-55 Butt Top Bottom MD 0' 2,505' TVD 0' 2,276' 17-1/2" hole, cmt w/ 1,200 sks & 200 sks of Class G Conductor 20" 94 ppf 0.50" wall thickness Top Bottom MD 0' 114' TVD 0' 114' Production Casing 9-5/8" 47 ppf N-80 Butt Top Bottom MD 0' 8,770' TVD 0' 7,674' 12-1/4" hole cmt w/ 3,000 sks of Class G (and many remedial squeezes on rig) Depth 12' 73' 2,530' 5,513' 5,551' to 5,564' 5,596'5,662' to 5,722' 5,753' to 5,793'5,986' to 6,046' 6,000' to 6,030' 6,076' to 6,176' 6,207'6,241' to 6,250' 6,281'7,428' 7,463' to 7,481'7,513' 7,546' Depth 12' 2,457' 5,480' 5,553' to 5,564'5,594' Jewelry 2-7/8" Long String Cameron Split Hanger1. 3-1/2" x 2-7/8" Crossover 2. Otis "XA" sleeve3. Otis "XA" sleeve 4. Baker Dual Hydraulic Packer 5. Otis "XA" sleeve 6. Baker Blast Joints7. Baker Blast Joints 8. Baker Blast Joints9. 1" ID Tubing Patch (installed 5/79) 10. Baker Blast Joints 11. Otis "XA" Sleeve12. Baker Single Hydraulic packer 13. Otis "XA" Sleeve14. Otis "XA" Sleeve 15. Baker Model D Pkr w/Tbg Locator & Seal16. Otis "X" Nipple 17. Bottom of Mule Shoe Jewelry 3-1/2" Short String Cameron Split Hanger A. Otis "XA" Sleeve B. Otis "XA" Sleeve C. Baker Dual Hydraulic PackerD. Otis "XN" Nipple 2A B C, 4 D 3 6 7 9 10 8 5 1 11 12 13 14 15 16 17 Permit #: 177-029 API #: 50-133-20304-00-S01 Prop. Des: A - 028142 KB elevation: 98' (21' AGL) Latitude: Longitude: Spud: 7/19/1977 04:00 hrs TD: 8/6/1997 Rig Released: 9/28/1977 12:00hrs PA #: 891006367C Beluga (both tubing strings are S01) Well Name & Number: Municipality: Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 13- 8 Kenai Peninsula Borough ~1.5º / 100' @ 394' 8/10/1977 D Ambruz Lease: State: Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 31º → 17º RKB:98' (AMSL)21' (AGL) 9/28/23 PBTD: 8,245' MD 7,152' TVD Tubing 4-1/2''" Top Bottom MD 0' ~ 5100' PROPOSED DRAFT ToC in 9-5/8" x 12.25" OH 4650'(9/4/77 CBL after squeezes) CIBP @ ±5549' MD w/ ~25' cement CIBP @ ±5570CIBP @ ±5559' Cut ~5549' 9-5/8''X7'' Packer ~4750 and ~5100' 7'' X 4.5'' Packer ~5000' Casing 7" Top Bottom MD 0' ~ 5160' Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Well Name: KBU 13-08 API Number: 501332030400 Current Status: SI gas well Permit to Drill Number: 177029 Estimated Start Date: 10/05/23 Rig: 401 workover rig, Eline First Call Engineer: Brian Glasheen 9075451144 Second Call Engineer: Chad Helgeson (907) 229-4824 (C) AFE Number: Job Type: Uphole recomplete Current Bottom Hole Pressure: 1335 psi @ 5356’ TVD (Offset KBU 11-17X 5 ppg EMW) Maximum Expected BHP: 1335 psi @ 5356’ TVD (New perfs being added but lower pressure pool 6 ~ 245 psi) MPSP: 800 psi (0.1 psi/ft gas gradient) Brief Well Summary: KBU 13-08 was drilled and completed 1977. Multiple perfs were added and straddle via packers with one short string and one long string with sliding sleeve for selective production in the beluga pool. Well has been SI since 2006. Notes Regarding Wellbore Condition • 9 -5/8’’ TOC ~4650 per CBL 9-4-77 post squeezes • SL drifted 5559’ SLM with 2.7’’ gauge ring on the short string • SL drifted 5609’ SLM with 2.25’ gauge ring on the long string Objective: The purpose of this work is to plug back the Beluga Pool, decomplete the dual string completion, install 5.5’’ tubing and complete the well as a pool 6 storage well to help meet peak demand gas rates throughout the winter. Hilcorp requests a variance to 20 AAC 25.112 (c)(1)(E) for placing cement within 106 ft of the top perf. There is one packer (5551’) between the top perfs and proposed bottom of cement. This procedure proposes packer to be equivalent to a mechanical bridge plug. This procedure includes the steps to place a CIBP and cement as close to the packer as possible in the casing to meet 20 AAC 25.112 (c)(1) where the hydrocarbons are confined to their indigenous strata and will not migrate to surface, but they will greater than 100ft of the top of perforations, as required in the regulations. Top’s :Beluga/Upper Tyonek pool is defined from KU 41-18 and Pool 6 and Pool 5.2 are defined by KU 21-06 Top Kenai Beluga/Upper Tyonek Gas Pool: 5633’ MD, 4718’ TVD Top Pool 6: 5389’ MD, 4509’ TVD Top Pool 5.2: 5057’ MD, 4230’ TVD Eline: ( Note this is pre rig work and not the reservoir P&A) 1. RU to short string. Test lubricator to 250/3,000 psi. 2. RIH and set 3.5’’ CIBP at ~ 5570’ (just below packer in first full size joint) 3. Jet cut tubing 1-2’ above packer at ~5549’ MD 4. RU to Long string. Test lubricator to 250/3,000 psi. Uphole recomplete Well: KBU 13-08 Date: 09/21/23 5. RIH and set 2-7/8’’ CIBP at ~ 5570’ (6’ below packer inside first full joint of 2-7/8’’ ) 6. Jet cut tubing 1-2’ above packer at ~5549’ MD 7. CMIT-T (SS and LS) x IA to 1500 psi. Confirm CIBP are holding and casing integrity. (If fails a test packer run will be performed during the RWO) Pre-Rig Procedure: 8. Circulate at least one wellbore volume through both the SS an LS with 8.5 ppg KCL/ Produced water down tubing, taking returns up casing. Brief RWO Procedure: 9. MIRU 401 WO Rig, ancillary equipment, and lines. 10. Set BPV in SS and LS. ND Tree. NU BOPE 11. Provide AOGCC 24 hrs in advance of BOP test 12. Test to 2000 psi with 2-7/8’’ and 3-1/2’’ test joints 13. Bleed any pressure off tubing and casing. Pull BPV. Kill well as needed. 14. MU landing joint or spear and BOLDS. 15. PU on the LS tubing hanger. 16. Recover the tubing hanger. 17. POOH and lay down the 2-7/8” tubing. a. Tubing will be inspected. 18. PU on the SS tubing hanger. 19. Recover the tubing hanger. 20. POOH and lay down the 3-1/2” tubing. a. Tubing will be inspected. 21. RU ELINE 22. RIH with gauge ring to drift for 9-5/8’’ CIPB 23. RIH and set 9-5/8’’ CIBP just above cut tubing at 5549’MD 24. RIH and dump 25’ of cement on top of CIBP for res P&A. 25. RDMO ELINE 26. If pre rig CMIT after CIBP’s were set with Eline failed: a. RIH with 9-5/8’’ test/storm packer and set at 4750’MD b. Pressure test 9-5/8’’ to 1500 psi c. POOH and set at 100’ for wellhead CO 27. If CMIT after CIBP were set with Eline passed: a. RIH with 9-5/8’’ test/storm packer and set at 100’MD b. Pressure test to 500 psi 28. ND BOP, ND wellhead, Install new wellhead, Pressure test wellhead void, NU BOP, set test plug and test BOP’s. 29. RIH and pull 9-5/8’’ test/storm packer 30. Change out handling equipment, install casing crew tongs, and upper rams for handling 7” casing. 31. Perform BOP test on the 7” pipe rams on 7” test joint. 32. PU new 7’’ completion and RIH Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Material Notes 4-1/2'' 1 WLEG/ Mule shoe L-80 4-1/2'' 3' 4 1/2'' X Nip with RHC L-80 4-1/2'' 10' Pup Joint L-80 7'' 5' XO L-80 7'' 10' Pup Joint L-80 7'' 9”-5/8 X 7” Packer L-80 Tri point packer ~Set ~5100' MD 7'' 6' Pup Joint L-80 7'' Joints L-80 7'' 4' Pup Joint L-80 7'' 9”-5/8 X 7” Packer L-80 Tri point packer ~Set ~4750' MD 7'' 6' Pup Joint L-80 7'' Joints L-80 7'' Space out PUPS L-80 7'' 1 joint L-80 7'' PUP L-80 7'' Tubing Hanger L-80 33. Space out and land the hanger. 34. Note PU (Pick Up) and SO (Slack Off) weights on tally. 35. RILDS. Lay down landing joint. 36. Pump 250 bbls of 1% KCL with 1% by volume Corrosion inhibitor down the IA. Taking returns up TBG. 37. Pump an additional 5 bbls of diesel freeze protect down the IA. (WSL discretion) 38. Swap to pumping down the 7’’. 39. Drop ball and rod and complete loading tubing and hydraulically set the packer as per Vendor setting procedure. 40. Pressure up and test the 7’’ Casing to 1500 psi for MIT-T. Bleed off the 7’’. Test the 9-5/8’’ annulus to 1500 psi. Record and notate all pressure tests (30 minutes) on chart. 41. RU SL Remove ball and rod and RHC 42. SL RIH and set TTP in X nip below 5100’ packer for isolation to install new wellhead. 43. ND BOP, Install new wellhead, Pressure test wellhead void, NU BOP, set test plug and test BOP’s. 44. Change out handling equipment, install casing crew tongs, and upper rams for handling 4-1/2” Tubing. 45. Perform BOP test with 4-1/2’’ test joint. Uphole recomplete Well: KBU 13-08 Date: 09/21/23 46. SL pull TTP from X nip 47. PU new 4-1/2’’ completion and RIH Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Material Notes 4-1/2'' 1 WLEG/ Mule shoe L-80 4-1/2'' 3' 4 1/2'' X Nip with RHC L-80 4-1/2'' 10' Pup Joint L-80 4-1/2'' 30 1 joint L-80 4-1/2'' 10' Pup Joint L-80 4-1/2'' 7”X4-1/2'' Packer L-80 Tri point packer ~Set ~5000' MD 4-1/2'' 6' Pup Joint L-80 4-1/2'' Joints L-80 4-1/2'' Space out PUPS L-80 4-1/2'' 1 joint L-80 4-1/2'' PUP L-80 4-1/2'' Tubing Hanger L-80 48. Space out and land the hanger. 49. Note PU (Pick Up) and SO (Slack Off) weights on tally. 50. RILDS. Lay down landing joint. 51. Pump 100 bbls of 1% KCL with 1% by volume Corrosion inhibitor down the IA. Taking returns up TBG. 52. Pump an additional 5 bbls of diesel freeze protect down the IA. (WSL discretion) 53. Swap to pumping down the 4-1/2’’ tubing. 54. Drop ball and rod and complete loading tubing and hydraulically set the packer as per Vendor setting procedure. 55. Pressure up and test the 4-1/2’’ tubing to 1500 psi for MIT-T. Bleed off the 4-1/2’’ tubing. Test the 7’’ annulus to 1500 psi. Record and notate all pressure tests (30 minutes) on chart. 56. ND BOP, NU tree and test 57. RDMO Rig 401. Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Post-Rig Procedure: Slickline: 1. RU Slickline. Test lubricator to 250/2,000 psi. 2. Pull ball and rod and RHC 3. RDMO Coil: 1. RU Coil. Test lubricator to 250/3,000 psi. 2. RIH and tag TOC. Stack as much weight as possible on cement to verify integrity. 3. Swap well over to N2. Reverse lift fluid from well. 4. RDMO Eline: 1. RU Eline. Test lubricator to 250/2,000 psi. 2. RIH and verify TOC via tag. Confirm 25’ of cement. If needed dump more cement to reach 25’ of cement. 3. Perforate the below sands in pool 6 from the bottom up: 4. Pool Sand Top MD Btm. MD Feet Pool 6 Pool 6 C1 5,421 5,501 80 5. RDMO Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Rig BOPE 401 Diagram 4. Existing Tree/Wellhead 5. Proposed Tree/Wellhead 6. Coil BOP Diagram 7. Nitrogen SOP 8. Blank RWO Changes Form 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,770 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 4,760psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng brian.glasheen@hilcorp.com 907-564-5277 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: SS 3-1/2" PRESENT WELL CONDITION SUMMARY Brian Glasheen, Operations Engineer AOGCC USE ONLY Tubing Grade: 9.2# / N-80 Tubing MD (ft): 5,595Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 177-029 50-133-20304-00-00 Hilcorp Alaska, LLC Proposed Pools: 6.4# / N-80 TVD Burst 4,686' 6,870psi 2,276' Size 114' 2,505' MD See Attached Schematic 3,090psi 114'114' 2,505' October 5, 2023 LS 2-7/8" 8,770' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 13-08CO 510C Sterling Gas Pool 6 7,674'9-5/8" ~800 psi 8,770' 8,245' Length See Schematic; N/A See Schematic; N/A 7,664 8,245 7,152 Kenai Beluga-Up Tyonek Gas 20" 13-3/8" See Attached Schematic m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:53 am, Sep 29, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.09.29 09:20:27 - 08'00' Noel Nocas (4361) 323-536 CDW 10-03-2023 bjm bjm CT BOP test to 2000 psi. Convert to Gas Storage Production Well SFD 10-404 Sterling Gas Pool 6 X bjm Perform weight test on cement plug and verify top of cement depth-corrected to ELine MD. BJM 10/4/23 GSGSTOR X SFD 10/4/2023 X DSR-9/29/23 BoP test to 2000 psi Well shall be used only for production from the gas storage pool unless the requirements of SIO 7A and 20 AAC 25.252 are met. Perforate New Pool P Service *&:JLC 10/5/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.05 11:24:43 -08'00'10/05/23 RBDMS JSB 100523 Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Well Name: KBU 13-08 API Number: 501332030400 Current Status: SI gas well Permit to Drill Number: 177029 Estimated Start Date: 10/05/23 Rig: 401 workover rig, Eline First Call Engineer: Brian Glasheen 9075451144 Second Call Engineer: Chad Helgeson (907) 229-4824 (C) AFE Number: Job Type:Uphole recomplete Current Bottom Hole Pressure: 1335 psi @ 5356’ TVD (Offset KBU 11-17X 5 ppg EMW) Maximum Expected BHP: 1335 psi @ 5356’ TVD (New perfs being added but lower pressure pool 6 ~ 245 psi) MPSP: 800 psi (0.1 psi/ft gas gradient) Brief Well Summary: KBU 13-08 was drilled and completed 1977. Multiple perfs were added and straddle via packers with one short string and one long string with sliding sleeve for selective production in the beluga pool. Well has been SI since 2006. Notes Regarding Wellbore Condition x 9 -5/8’’ TOC ~4650 per CBL 9-4-77 post squeezes x SL drifted 5559’ SLM with 2.7’’ gauge ring on the short string x SL drifted 5609’ SLM with 2.25’ gauge ring on the long string Objective: The purpose of this work is to plug back the Beluga Pool, decomplete the dual string completion, install 5.5’’ tubing and complete the well as a pool 6 storage well to help meet peak demand gas rates throughout the winter. Hilcorp requests a variance to 20 AAC 25.112 (c)(1)(E) for placing cement within 106 ft of the top perf. There is one packer (5551’) between the top perfs and proposed bottom of cement. This procedure proposes packer to be equivalent to a mechanical bridge plug. This procedure includes the steps to place a CIBP and cement as close to the packer as possible in the casing to meet 20 AAC 25.112 (c)(1) where the hydrocarbons are confined to their indigenous strata and will not migrate to surface, but they will greater than 100ft of the top of perforations, as required in the regulations. Top’s :Beluga/Upper Tyonek pool is defined from KU 41-18 and Pool 6 and Pool 5.2 are defined by KU 21-06 Top Kenai Beluga/Upper Tyonek Gas Pool: 5633’ MD, 4718’ TVD Top Pool 6: 5389’ MD, 4509’ TVD Top Pool 5.2: 5057’ MD, 4230’ TVD Eline: ( Note this is pre rig work and not the reservoir P&A) 1. RU to short string. Test lubricator to 250/3,000 psi. 2. RIH and set 3.5’’ CIBP at ~ 5559’ (Inside packer) 3. Jet cut tubing 1-2’ above packer at ~5549’ MD 4. RU to Long string. Test lubricator to 250/3,000 psi. plug back the Beluga Pool, decomplete the dual string completion, install 5.5’’ tubing and Producer only. SFD Superseded complete the well as a pool 6 storage well to help meet peak demand gas rates throughout the winter. d c Uphole recomplete Well: KBU 13-08 Date: 09/21/23 5. RIH and set 2-7/8’’ CIBP at ~ 5570’ (6’ below packer inside first full joint of 2-7/8’’ ) 6. Jet cut tubing 1-2’ above packer at ~5549’ MD 7. CMIT-T (SS and LS) x IA to 1500 psi. Confirm CIBP are holding and casing integrity. (If fails a test packer run will be performed during the RWO) Pre-Rig Procedure: 8. Circulate at least one wellbore volume through both the SS an LS with 8.5 ppg KCL/ Produced water down tubing, taking returns up casing. Brief RWO Procedure: 9. MIRU 401 WO Rig, ancillary equipment, and lines. 10. Set BPV in SS and LS. ND Tree. NU BOPE 11. Provide AOGCC 24 hrs in advance of BOP test 12. Test to 2000 psi with 2-7/8’’ and 3-1/2’’ test joints 13. Bleed any pressure off tubing and casing. Pull BPV. Kill well as needed. 14. MU landing joint or spear and BOLDS. 15. PU on the LS tubing hanger. 16. Recover the tubing hanger. 17. POOH and lay down the 2-7/8” tubing. a. Tubing will be inspected. 18. PU on the SS tubing hanger. 19. Recover the tubing hanger. 20. POOH and lay down the 3-1/2” tubing. a. Tubing will be inspected. 21. RU ELINE 22. RIH with gauge ring to drift for 9-5/8’’ CIPB 23. RIH and set 9-5/8’’ CIBP just above cut tubing at 5549’MD 24. RIH and dump 25’ of cement on top of CIBP for res P&A. 25. RDMO ELINE 26. If pre rig CMIT after CIBP’s were set with Eline failed: a. RIH with 9-5/8’’ test/storm packer and set at 4750’MD b. Pressure test 9-5/8’’ to 1500 psi c. POOH and set at 100’ for wellhead CO 27. If CMIT after CIBP were set with Eline passed: a. RIH with 9-5/8’’ test/storm packer and set at 100’MD 28. ND BOP, ND wellhead, Install new wellhead, Pressure test wellhead void, NU BOP, set test plug and test BOP’s. 29. RIH and pull 9-5/8’’ test/storm packer 30. PU new 5-1/2’’ completion and RIH Superseded Pressure test storm packer from below before ND. -bjm Need to verify plug integrity by either weight testing with 15k lbs, or tag and pressure test per 20AAC25.112(g) Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Material Notes 5-1/2'' 1 WLEG/ Mule shoe L-80 5-1/2'' 3' 5 1/2'' X Nip with RHC L-80 5-1/2'' 10' Pup Joint L-80 5-1/2'' 1 XO L-80 5-1/2'' 9”-5/8 X 5-1/2” Packer L-80 Tri point packer ~Set ~5100' MD 5-1/2'' 6' Pup Joint L-80 5-1/2'' Joints L-80 5-1/2'' 4' Pup Joint L-80 5-1/2'' 9”-5/8 X 5-1/2” Packer L-80 Tri point packer ~Set ~4750' MD 5-1/2'' 6' Pup Joint L-80 5-1/2'' Joints L-80 5-1/2'' Space out PUPS L-80 5-1/2'' 1 joint L-80 5-1/2'' PUP L-80 5-1/2'' Tubing Hanger L-80 31. Space out and land the hanger. 32. Note PU (Pick Up) and SO (Slack Off) weights on tally. 33. RILDS. Lay down landing joint. 34. Pump 250 bbls of 1% KCL with 1% by volume Corrosion inhibitor down the IA. Taking returns up TBG. 35. Pump an additional 5 bbls of diesel freeze protect down the IA. (WSL discretion) 36. Swap to pumping down the TBG. 37. Drop ball and rod and complete loading tubing and hydraulically set the packer as per Vendor setting procedure. 38. Pressure up and test the tubing to 1500 psi for MIT-T. Bleed off the tubing. Test the IA to 1500 psi for MIT-IA. Record and notate all pressure tests (30 minutes) on chart. 39. ND BOP, NU tree and test 40. RDMO Rig 401. 38.Pressure up and test the tubing to 1500 psi for MIT-T. Bleed off the tubing. Test the IA to 1500 psi for MIT-IA. Record and notate all pressure tests (30 minutes) on chart. Superseded Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Post-Rig Procedure: Slickline: 1. RU Slickline. Test lubricator to 250/2,000 psi. 2. Pull ball and rod and RHC 3. RDMO Coil: 1. RU Coil. Test lubricator to 250/3,000 psi. 2. RIH and tag TOC. 3. Swap well over to N2. Reverse lift fluid from well. 4. RDMO Eline: 1. RU Eline. Test lubricator to 250/2,000 psi. 2. Perforate the below sands in pool 6 from the bottom up: 3. Pool Sand Top MD Btm. MD Feet Pool 6 Pool 6 C1 5,421 5,501 80 4. RDMO Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Rig BOPE 401 Diagram 4. Existing Tree/Wellhead 5. Proposed Tree/Wellhead 6. Coil BOP Diagram 7. Nitrogen SOP 8. Blank RWO Changes Form Superseded Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Well Name: KBU 13-08 API Number: 501332030400 Current Status: SI gas well Permit to Drill Number: 177029 Estimated Start Date: 10/05/23 Rig: 401 workover rig, Eline First Call Engineer: Brian Glasheen 9075451144 Second Call Engineer: Chad Helgeson (907) 229-4824 (C) AFE Number: Job Type: Uphole recomplete Current Bottom Hole Pressure: 1335 psi @ 5356’ TVD (Offset KBU 11-17X 5 ppg EMW) Maximum Expected BHP:1335 psi @ 5356’ TVD (New perfs being added but lower pressure pool 6 ~ 245 psi) MPSP:800 psi (0.1 psi/ft gas gradient) Brief Well Summary: KBU 13-08 was drilled and completed 1977. Multiple perfs were added and straddle via packers with one short string and one long string with sliding sleeve for selective production in the beluga pool. Well has been SI since 2006. Notes Regarding Wellbore Condition x 9 -5/8’’ TOC ~4650 per CBL 9-4-77 post squeezes x SL drifted 5559’ SLM with 2.7’’ gauge ring on the short string x SL drifted 5609’ SLM with 2.25’ gauge ring on the long string Objective: The purpose of this work is to plug back the Beluga Pool, decomplete the dual string completion, install 5.5’’ tubing and complete the well as a pool 6 storage well to help meet peak demand gas rates throughout the winter. Hilcorp requests a variance to 20 AAC 25.112 (c)(1)(E) for placing cement within 106 ft of the top perf. There is one packer (5551’) between the top perfs and proposed bottom of cement. This procedure proposes packer to be equivalent to a mechanical bridge plug. This procedure includes the steps to place a CIBP and cement as close to the packer as possible in the casing to meet 20 AAC 25.112 (c)(1) where the hydrocarbons are confined to their indigenous strata and will not migrate to surface, but they will greater than 100ft of the top of perforations, as required in the regulations. Top’s :Beluga/Upper Tyonek pool is defined from KU 41-18 and Pool 6 and Pool 5.2 are defined by KU 21-06 Top Kenai Beluga/Upper Tyonek Gas Pool: 5633’ MD, 4718’ TVD Top Pool 6: 5389’ MD, 4509’ TVD Top Pool 5.2: 5057’ MD, 4230’ TVD Eline: ( Note this is pre rig work and not the reservoir P&A) 1. RU to short string. Test lubricator to 250/3,000 psi. 2. RIH and set 3.5’’ CIBP at ~ 5559’ (Inside packer) 3. Jet cut tubing 1-2’ above packer at ~5549’ MD 4. RU to Long string. Test lubricator to 250/3,000 psi. Variance approved. -bjm Approved for a Pool 6 producer only. Not approved for injection. Uphole recomplete Well: KBU 13-08 Date: 09/21/23 5. RIH and set 2-7/8’’ CIBP at ~ 5570’ (6’ below packer inside first full joint of 2-7/8’’ ) 6. Jet cut tubing 1-2’ above packer at ~5549’ MD 7. CMIT-T (SS and LS) x IA to 1500 psi. Confirm CIBP are holding and casing integrity. (If fails a test packer run will be performed during the RWO) Pre-Rig Procedure: 8. Circulate at least one wellbore volume through both the SS an LS with 8.5 ppg KCL/ Produced water down tubing, taking returns up casing. Brief RWO Procedure: 9. MIRU 401 WO Rig, ancillary equipment, and lines. 10. Set BPV in SS and LS. ND Tree. NU BOPE 11. Provide AOGCC 24 hrs in advance of BOP test 12. Test to 2000 psi with 2-7/8’’ and 3-1/2’’ test joints 13. Bleed any pressure off tubing and casing. Pull BPV. Kill well as needed. 14. MU landing joint or spear and BOLDS. 15. PU on the LS tubing hanger. 16. Recover the tubing hanger. 17. POOH and lay down the 2-7/8” tubing. a. Tubing will be inspected. 18. PU on the SS tubing hanger. 19. Recover the tubing hanger. 20. POOH and lay down the 3-1/2” tubing. a. Tubing will be inspected. 21. RU ELINE 22. RIH with gauge ring to drift for 9-5/8’’ CIPB 23. RIH and set 9-5/8’’ CIBP just above cut tubing at 5549’MD 24. RIH and dump 25’ of cement on top of CIBP for res P&A. 25. RDMO ELINE 26. If pre rig CMIT after CIBP’s were set with Eline failed: a. RIH with 9-5/8’’ test/storm packer and set at 4750’MD b. Pressure test 9-5/8’’ to 1500 psi c. POOH and set at 100’ for wellhead CO 27. If CMIT after CIBP were set with Eline passed: a. RIH with 9-5/8’’ test/storm packer and set at 100’MD b. Pressure test to 500 psi 28. ND BOP, ND wellhead, Install new wellhead, Pressure test wellhead void, NU BOP, set test plug and test BOP’s. 29. RIH and pull 9-5/8’’ test/storm packer 30. PU new 5-1/2’’ completion and RIH Pressure test to 500 psi. bjm Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Material Notes 5-1/2'' 1 WLEG/ Mule shoe L-80 5-1/2'' 3' 5 1/2'' X Nip with RHC L-80 5-1/2'' 10' Pup Joint L-80 5-1/2'' 1 XO L-80 5-1/2'' 9”-5/8 X 5-1/2” Packer L-80 Tri point packer ~Set ~5100' MD 5-1/2'' 6' Pup Joint L-80 5-1/2'' Joints L-80 5-1/2'' 4' Pup Joint L-80 5-1/2'' 9”-5/8 X 5-1/2” Packer L-80 Tri point packer ~Set ~4750' MD 5-1/2'' 6' Pup Joint L-80 5-1/2'' Joints L-80 5-1/2'' Space out PUPS L-80 5-1/2'' 1 joint L-80 5-1/2'' PUP L-80 5-1/2'' Tubing Hanger L-80 31. Space out and land the hanger. 32. Note PU (Pick Up) and SO (Slack Off) weights on tally. 33. RILDS. Lay down landing joint. 34. Pump 250 bbls of 1% KCL with 1% by volume Corrosion inhibitor down the IA. Taking returns up TBG. 35. Pump an additional 5 bbls of diesel freeze protect down the IA. (WSL discretion) 36. Swap to pumping down the TBG. 37. Drop ball and rod and complete loading tubing and hydraulically set the packer as per Vendor setting procedure. 38. Pressure up and test the tubing to 1500 psi for MIT-T. Bleed off the tubing. Test the IA to 1500 psi for MIT-IA. Record and notate all pressure tests (30 minutes) on chart. 39. ND BOP, NU tree and test 40. RDMO Rig 401. Provide AOGCC 24 hrs notice for opportunity to witness MITT & MITIA. -bjm Uphole recomplete Well: KBU 13-08 Date: 09/21/23 Post-Rig Procedure: Slickline: 1. RU Slickline. Test lubricator to 250/2,000 psi. 2. Pull ball and rod and RHC 3. RDMO Coil: 1. RU Coil. Test lubricator to 250/3,000 psi. 2. RIH and tag TOC. Stack as much weight as possible on cement to verify integrity. 3. Swap well over to N2. Reverse lift fluid from well. 4. RDMO Eline: 1. RU Eline. Test lubricator to 250/2,000 psi. 2. RIH and verify TOC via tag. Confirm 25’ of cement. If needed dump more cement to reach 25’ of cement. 3. Perforate the below sands in pool 6 from the bottom up: 4. Pool Sand Top MD Btm. MD Feet Pool 6 Pool 6 C1 5,421 5,501 80 5. RDMO Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Rig BOPE 401 Diagram 4. Existing Tree/Wellhead 5. Proposed Tree/Wellhead 6. Coil BOP Diagram 7. Nitrogen SOP 8. Blank RWO Changes Form Need to confirm cement top depth control referenced to ELMD to verify 25' of cement on CIBP. -bjm Tyonek Isolation: Cement Retainer @ 8,245' Permanent Packer @ 8,250' KBU 13- 8 Pad 41-18 804' FNL, 685' FWL, Sec. 18, T4N, R11W, S.M. TD: 8,770' MD 7,664' TVD Perforations: Date Interval Condition Zone 8/11/77 4,820'-4,822' Sqz,d w/ 500 sks Sterling 8/11/77 5,058'-5,060' Sqz,d w/ 150 sks Upper Beluga 8/10/77 5,398'-5,400' Sqz,d w/ 500 sks Upper Beluga 8/10/77 5,658'-5,660' Sqz,d w/ 200 sks Upper Beluga 9/8/77 5,658'-5,694' Production Upper Beluga 9/9/77 5,752'-5,770' Production Upper Beluga 9/15/77 5,755'-5,765' Production Upper Beluga 9/10/77 5,804'-5,830' Sqz,d w/ 250 sks Upper Beluga 9/10/77 5,872'-5,912' Sqz,d w/ 250 sks Upper Beluga 9/15/77 6,005'-6,025' Production Upper Beluga 9/15/77 6,092'-6,098' Production Upper Beluga 9/14/77 6,142'-6,148' Production Upper Beluga 8/10/77 6,298'-6,300' Sqz,d w/ 200 sks Middle Beluga 8/24/77 6,344'-6,384' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,446'-6,458' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,466'-6,474' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,790'-6,804' Sqz,d w/ 600 sks Middle Beluga 9/5/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 9/6/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 8/25/77 6,820'-6,845' Sqz,d w/ 600 sks Middle Beluga 8/25/77 6,852'-6,882' Sqz,d w/ 600 sks Middle Beluga 8/25/77 7,004'-7,018' Sqz,d w/ 600 sks Middle Beluga 9/5/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 9/6/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 8/25/77 7,040'-7,076' Sqz,d w/ 400 sks Middle Beluga 8/25/77 7,244'-7,264' Sqz'd w/ 200 sks Middle Beluga 8/10/77 7,568'-7,570' Sqz,d w/ 150 sks Lower Beluga 8/20/77 7,578'-7,628' Production Lower Beluga 8/22/77 7,642'-7,662' Production Lower Beluga 8/22/77 7,672'-7,680' Production Lower Beluga 8/22/77 7,776'-7,812' Production Lower Beluga 8/21/77 7,840'-7,865' Production Lower Beluga 8/21/77 7,892'-7,916' Production Lower Beluga 8/21/77 8,202'-8,218' Production Lower Beluga 8/10/77 8,308'-8,310' Sqz,d w/ 150 sks Tyonek 8/18/77 8,334'-8,364' Isolated Tyonek 8/18/77 8,660'-8,680' Isolated Tyonek Surface Casing 13-3/8" 61 ppf K-55 Butt Top Bottom MD 0' 2,505' TVD 0' 2,276' 17-1/2" hole, cmt w/ 1,200 sks & 200 sks of Class G Conductor 20" 94 ppf 0.50" wall thickness Top Bottom MD 0' 114' TVD 0' 114' Production Casing 9-5/8" 47 ppf N-80 Butt Top Bottom MD 0' 8,770' TVD 0' 7,674' 12-1/4" hole cmt w/ 3,000 sks of Class G (and many remedial squeezes on rig) Depth 12' 73' 2,530' 5,513' 5,551' to 5,564'5,596' 5,662' to 5,722' 5,753' to 5,793'5,986' to 6,046' 6,000' to 6,030' 6,076' to 6,176' 6,207'6,241' to 6,250' 6,281' 7,428' 7,463' to 7,481' 7,513' 7,546' Depth 12' 2,457'5,480' 5,553' to 5,564' 5,594' Jewelry 2-7/8" Long String Cameron Split Hanger 1. 3-1/2" x 2-7/8" Crossover 2. Otis "XA" sleeve3. Otis "XA" sleeve 4. Baker Dual Hydraulic Packer 5. Otis "XA" sleeve 6. Baker Blast Joints7. Baker Blast Joints 8. Baker Blast Joints 9. 1" ID Tubing Patch (installed 5/79)10. Baker Blast Joints 11. Otis "XA" Sleeve 12. Baker Single Hydraulic packer 13. Otis "XA" Sleeve14. Otis "XA" Sleeve 15. Baker Model D Pkr w/Tbg Locator & Seal16. Otis "X" Nipple 17. Bottom of Mule Shoe Jewelry 3-1/2" Short String Cameron Split Hanger A. Otis "XA" SleeveB. Otis "XA" Sleeve C. Baker Dual Hydraulic Packer D. Otis "XN" Nipple 2A B C, 4 D 3 6 7 9 10 8 5 1 11 12 13 14 15 16 17 Permit #: 177-029 API #: 50-133-20304-00-S01 Prop. Des: A - 028142 KB elevation: 98' (21' AGL) Latitude: Longitude: Spud: 7/19/1977 04:00 hrs TD: 8/6/1997 Rig Released: 9/28/1977 12:00hrs PA #: 891006367C Beluga (both tubing strings are S01) Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 13- 8 Kenai Peninsula Borough 5,658' - 8,218' ~1.5º / 100' @ 394' 8/10/1977 Ryan Rupert Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 4,740' - 7,127' 31º ĺ 17º RKB:98' (AMSL)21' (AGL) 8/31/2020 PBTD: 8,245' MD 7,152' TVD Short String Tubing 3-1/2" 9.2 ppf N-80 Butt Top Bottom MD 0' 5,595' TVD 0' 4,686' Long String Tubing 2-7/8" 6.4 ppf N-80 Armco Seal-lok Top Bottom MD 0' 7,546' TVD 0' 6,487' SCHEMATIC ToC in 9-5/8" x 12.25" OH 4650'(9/4/77 CBL after squeezes) Tyonek Isolation: Cement Retainer @ 8,245' Permanent Packer @ 8,250' KBU 13- 8 Pad 41-18 804' FNL, 685' FWL, Sec. 18, T4N, R11W, S.M. TD: 8,770' MD 7,664' TVD Perforations: Date Interval Condition Zone Proposed ±5,421-5,501' TBD Pool 6 8/11/77 4,820'-4,822' Sqz,d w/ 500 sks Sterling 8/11/77 5,058'-5,060' Sqz,d w/ 150 sks Upper Beluga 8/10/77 5,398'-5,400' Sqz,d w/ 500 sks Upper Beluga 8/10/77 5,658'-5,660' Sqz,d w/ 200 sks Upper Beluga 9/8/77 5,658'-5,694' Production Upper Beluga 9/9/77 5,752'-5,770' Production Upper Beluga 9/15/77 5,755'-5,765' Production Upper Beluga 9/10/77 5,804'-5,830' Sqz,d w/ 250 sks Upper Beluga 9/10/77 5,872'-5,912' Sqz,d w/ 250 sks Upper Beluga 9/15/77 6,005'-6,025' Production Upper Beluga 9/15/77 6,092'-6,098' Production Upper Beluga 9/14/77 6,142'-6,148' Production Upper Beluga 8/10/77 6,298'-6,300' Sqz,d w/ 200 sks Middle Beluga 8/24/77 6,344'-6,384' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,446'-6,458' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,466'-6,474' Sqz'd w/ 450 sks Middle Beluga 8/25/77 6,790'-6,804' Sqz,d w/ 600 sks Middle Beluga 9/5/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 9/6/77 6,820'-6,840' Sqz,d w/ 300 sks Middle Beluga 8/25/77 6,820'-6,845' Sqz,d w/ 600 sks Middle Beluga 8/25/77 6,852'-6,882' Sqz,d w/ 600 sks Middle Beluga 8/25/77 7,004'-7,018' Sqz,d w/ 600 sks Middle Beluga 9/5/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 9/6/77 7,040'-7,076' Sqz'd w/ 200 sks Middle Beluga 8/25/77 7,040'-7,076' Sqz,d w/ 400 sks Middle Beluga 8/25/77 7,244'-7,264' Sqz'd w/ 200 sks Middle Beluga 8/10/77 7,568'-7,570' Sqz,d w/ 150 sks Lower Beluga 8/20/77 7,578'-7,628' Production Lower Beluga 8/22/77 7,642'-7,662' Production Lower Beluga 8/22/77 7,672'-7,680' Production Lower Beluga 8/22/77 7,776'-7,812' Production Lower Beluga 8/21/77 7,840'-7,865' Production Lower Beluga 8/21/77 7,892'-7,916' Production Lower Beluga8/21/77 8,202'-8,218' Production Lower Beluga 8/10/77 8,308'-8,310' Sqz,d w/ 150 sks Tyonek Surface Casing 13-3/8" 61 ppf K-55 Butt Top Bottom MD 0' 2,505' TVD 0' 2,276' 17-1/2" hole, cmt w/ 1,200 sks & 200 sks of Class G Conductor 20" 94 ppf 0.50" wall thickness Top Bottom MD 0' 114' TVD 0' 114' Production Casing 9-5/8" 47 ppf N-80 Butt Top Bottom MD 0' 8,770' TVD 0' 7,674' 12-1/4" hole cmt w/ 3,000 sks of Class G (and many remedial squeezes on rig) Depth 12' 73' 2,530'5,513' 5,551' to 5,564'5,596' 5,662' to 5,722' 5,753' to 5,793' 5,986' to 6,046' 6,000' to 6,030'6,076' to 6,176' 6,207' 6,241' to 6,250' 6,281' 7,428' 7,463' to 7,481' 7,513' 7,546' Depth 12' 2,457' 5,480' 5,553' to 5,564'5,594' Jewelry 2-7/8" Long String Cameron Split Hanger 1. 3-1/2" x 2-7/8" Crossover 2. Otis "XA" sleeve 3. Otis "XA" sleeve 4. Baker Dual Hydraulic Packer 5. Otis "XA" sleeve 6. Baker Blast Joints 7. Baker Blast Joints 8. Baker Blast Joints 9. 1" ID Tubing Patch (installed 5/79)10. Baker Blast Joints 11. Otis "XA" Sleeve12. Baker Single Hydraulic packer 13. Otis "XA" Sleeve 14. Otis "XA" Sleeve 15. Baker Model D Pkr w/Tbg Locator & Seal16. Otis "X" Nipple 17. Bottom of Mule Shoe Jewelry 3-1/2" Short String Cameron Split Hanger A. Otis "XA" Sleeve B. Otis "XA" Sleeve C. Baker Dual Hydraulic PackerD. Otis "XN" Nipple 2A B C, 4 D 3 6 7 9 10 8 5 1 11 12 13 14 15 16 17 Permit #: 177-029 API #: 50-133-20304-00-S01 Prop. Des: A - 028142 KB elevation: 98' (21' AGL) Latitude: Longitude: Spud: 7/19/1977 04:00 hrs TD: 8/6/1997 Rig Released: 9/28/1977 12:00hrs PA #: 891006367C Beluga (both tubing strings are S01) Well Name & Number: Municipality: Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 13- 8 Kenai Peninsula Borough ~1.5º / 100' @ 394' 8/10/1977 D Ambruz Lease: State: Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 31º ĺ 17º RKB:98' (AMSL)21' (AGL) 9/28/23 PBTD: 8,245' MD 7,152' TVD Tubing 5-1/2''" Top Bottom MD 0' ~ 5115' PROPOSED DRAFT ToC in 9-5/8" x 12.25" OH 4650'(9/4/77 CBL after squeezes) CIBP @ ±5549' MD w/ ~25' cement CIBP @ ±5570CIBP @ ±5559' B Cut ~5549' 9-5/8''X 5-1/2'' Packer ~4750 and ~5100' Kenai Gas Field KBU 13-08 BOP Rig 401 9/28/2023 Choke and Kill valves 2 1/16 5M Mud Cross 4-1/16" 5M EFO Schrader 13 5/8-5000 Shaffer SL 2 7/8-5 ½’’ variables Blind Kenai Gas Field KBU 13-08 Current 09/21/2023 Tree, block, dual, Cameron type F, 11 5M X 3 1/8 5M X 3 1/8 5M, EE trim, 5 3/64 centers, single master swab, 3 1/8 5M SSO 3 1/8 5M 5 bolt segmented top Tubing hanger, Dual, CIW- DCB, 11 X 3 1/2 EUE lift X 3 ½ IBT susp, w/ 3'’ type H BPV profile, 5 3/64 centers Kenai Gas Field KBU 13-08 20 X13 3/8 x 9 5/8 x 3 1/2 x 2 7/8 Tubing head, CIW-DCB, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, X bottom prep Casing spool, OCT-22-BP, 21 ¼ 2M X 13 5/8 5M, w/ 2- 2 1/16 5M SSO, OO bottom prep Casing head, OCT-22, 21 ¼ 2M X SOW, w/ 2- 2'’ LPO 20'’ 13 3/8'’ 9 5/8'’ 2 7/8'’3 ½’’ Tubing head, OCT-TC-00, 13 5/8 5M X 11 5M, w/ 2- 2 1/16 5M EFO Same AnnulusDSA, 13 5/8 3M x 11 5M Kenai Gas Field KBU 13-08 Proposed 09/21/2023 Kenai Gas Field KBU 13-08 20 X13 3/8 x 9 5/8 x 5 1/2 Casing spool, OCT-22-BP, 21 ¼ 2M X 13 5/8 5M, w/ 2- 2 1/16 5M SSO, OO bottom prep Casing head, OCT-22, 21 ¼ 2M X SOW, w/ 2- 2'’ LPO 20'’ 13 3/8'’ 9 5/8'’ Valve, Master, WKM-M, 5 1/8 5M FE, HWO, EE trim Valve, Upper master, WKM-M, 5 1/8 5M FE, HWO, EE trim Valve, Swab, WKM-M 5 1/8 5M FE, HWO, EE trim BHTA, Otis, 5 1/8 5M FE x 9.5 Otis quick union top Tubing hanger, CW, 11 x 5 ½ BTC bottom x 6.125'’ LH stub acme box top, w/ 7'’ od neck, 5'’ type H BPV profile, DD-NL material Valve, Wing, SSV, WKM-M, 4 1/16 5M or 3 1/8 5M FE, w/ 15'’ Hydraulic operator Adapter, Cactus-EN-7'’, 11 5M stdd x 5 1/8 5M stdd top, w/ 2- 1'’npt control line exits 5 ½’’ Tubing head, Cactus, 13 5/8 5M x 11 5M w/ 2- 2 1/16 5M SSO, w/ 9 5/8 HPS bottom STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d R i g W o r k O v e r S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l K B U 1 3 - 0 8 ( P T D 1 7 7 - 0 2 9 ) Su n d r y # : X X X - X X X An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a te d t o t h e AO G C C by t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . Se c Pa g e Da t e Pr o c e d u r e C h a n g e Ne w 4 0 3 Re q u i r e d ? Y / N HA K Pr e p a r e d By (I n i t i a l s ) HA K Ap p r o v e d By (I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : A s s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : F i r s t C a l l O p e r a t i o n s E n g i n e e r D a t e CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brian Glasheen To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); Guhl, Meredith D (OGC); McLellan, Bryan J (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL] KBU 13-08 (PTD 177-029, Sundry 323-536 - Convert from Producer to Gas Storage Well Date:Monday, October 2, 2023 4:20:38 PM Hey Steve, Thanks for taking my call. For KBU 13-08 we do not plan to inject in the well and only plan to use it as a producer. Its current pad does not have injection capabilities. TOC was ~4650 per the CBL ran post perf squeeze and is 771’ above our planed perf depth. Thanks Brian Glasheen Ops Engineer 907-545-1144 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, October 2, 2023 3:16 PM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL] KBU 13-08 (PTD 177-029, Sundry 323-536 - Convert from Producer to Gas Storage Well Brian, I’m reviewing Hilcorp’s Sundry Application to convert KBU 13-08 from a producer to a gas storage well. Please review the requirements of Regulation 20 AAC 25.252—Underground Disposal of Oil Field Wastes and Underground Storage of Hydrocarbons—and provide all information required to support this application. Thanks and Be Well, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brian Glasheen To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] RE: KBU 13-08 (PTD 177-029) questions Date:Tuesday, October 3, 2023 12:56:16 PM Attachments:KGF Pad 41-18 660ft radius of wells for SSSV analysis .pdf KBU 13-08 RWO to 5.5 in tubing.pdf Hey Bryan, I made the correction in the program to meet the requests below. I highlighted them in red. Attached is the 660’ map as well. Thanks Brian Glasheen Ops Engineer 907-545-1144 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, October 3, 2023 11:49 AM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: [EXTERNAL] RE: KBU 13-08 (PTD 177-029) questions Brian, Please also send the aerial image showing the 660’ radius circle around it to verify that a SSSV is not required per 20 AAC 25.265(d)(2). Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Tuesday, October 3, 2023 11:47 AM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: KBU 13-08 (PTD 177-029) questions Brian, A couple points for clarification on the sundry application. 1. How will you verify the cement P&A plug has integrity? Weight test with 15k lbs is probably the best since pressure test won’t tell you anything. See 20 AAC 25.112(e) 2. Need to pressure test the storm packer at 100’ before nipple down tree. 3. Step 36: You will circ out the freeze protect you just put in place by pumping down the tubing. We will be dropping ball and rod and not circulating the IA. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1(' j '~ MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU 2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177-029 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-179 KBU 44-06 SGÞ~~NEt:\ JAN 2 @ 2004 . Union Oil and Gas Division: Western Region Union Oil Company o ,lifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union August 26, 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE INTENTION'S CLU #1 & #3 - KBU 13-8 Dear Mr. Chatterton: Attached for your approval are Sundry Notice of Intention's for CLU #1 & #3, Cannery Loop Unit, and KBU 13-8, Kenai Beluga Unit. Please return the approved Sundry's to the undersigned. L0C/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ,.,IL AND GAS CONSERVATION C,_ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] · 2. Name of Operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 77-29 3. Address 8. APl Number P0 BOX 6247 ANCHORAGE AK 99502 50- 733-20304 4. Location of Well 804'S & 685'W of NE Cdr., Sec. 18, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 98' MSL 6. Lease Designation and Serial No. A-028142 9. Unit or Lease Name Kenai Beluga Unit 10. Well Number KBU 13-8 11. Field and Pool Kenai Gas Field 12. (Submit in Triplicate) Perforate ~;] Alter Casing [] Perforations Stimulate [] 'Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tu .bing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Procedure: 1.) 2.) 3.) 4.) 5.) 7.) 8.) 9.) 10.) Rig down equipment. Move in & rig up on well KBU 13-8. Install BPV's, kill well, remove tree, install & test BOPE to 3000 psi. Recover the dual 3 1/2" X 2 7/8" tubing string. Mill over & recover packers ~ + 5550', + 6241' & + 7463'. Clean out to retainer $ + 8245T. - - Test the Beluga Sands, Upper & Lower for sand/water production. Lower Beluga 7 perf'd intervals between ± 7578' &_+ 8218'. Upper Beluga 5 perf'd intervals between_+ 5658' ~ 6148'. Recomplete as dual 3 1/2" - 3 1/2" Beluga/Sterling gas producer perforating the Sterling pool 6 in 4 zones between + 5426' & + 5632'. Install BPV's, remove BOPE's, & install & test tree] - Place well on production. ~ E ¢ E IV E D AUG 2 ~,~ 1§8§ Signed ~ 0. ~C~ing The space below for Commission use correct to the best of my knowledge. Alaska 0il & Gas Cons. Commission Anchorage ENVIRONMENTAL SPECIALIST Title 08-22-85 Date Conditions of Approval, if any: Approved by Form 10~,03 Rev. 7-1-80 COMMISSIONER /~pproved Copy ~turn,~d By Order of / the Commission Date and "Subsequent Reports" in Duplicate Union Oil and Gas D~.ivision' Western Region Union Oil Compan, .,f California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union October 17, 1984 Mr. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001Roucupine Drive Anchorage, Alaska 9~502 Dear Mr. Chatterton: SUNDRY NOTICE - KBU 13-8 Attached is a Sundry Notice showing corrected Lease Designation and Serial Number previously reported to you in error. Very truly yours, Lawrence O. Cutting Environmental Technician LOC:tj Attachment o¢¥ t Aias~,a Oil & Gas Cons. Oommissi°f~ Anchorage STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION ~_ .~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER)(2 2. Name of ~j~ 0IL COMPANY OF CALIFORNIA 7. Perrr~t~.,o29 - 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 733-20304 9. Unit or Lease Name KENAI BELUGA UNIT lO. Well Number KBU 13-8 11. Field and Pool 6. Lease Designation and Serial No. KENAI GAS FIELD A-028142 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 4. Location of Well 804'S & 685'W of NE corner, Sec. 18, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 98' MSL 12. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ' [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [~X] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is to correct Lease Designation and Serial Number previously reported in error. RECEIVED OCT 1 91984 Alaska Oil & Gas Cons. 60mrnissi0n Anchorage 14. I hereby~at the foregoing is true and correct to the best of my knowledge. Signed ,../~,-~~~~ C~ TitleENVIRONHENTAL TECHNICIAN The space below for Commission use Date 10/16/84 Conditions of Approval, if any: Approved by 11tlti1111 ~ _i~provea ,: " ~turnec~, By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate '~ ' STATE OF ALASKA ~: - ALASKA U,,_ AND GAS CONSERVATION C~, .... MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. UNION 0IL CONPANY OF CALIFORNIA 77-29 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5~_33-20304 4. Location of Well 804'5 & 685'W of NE corner, Sec. 18, T4N, RllW, SN. 5. Elevation in feet (indicate KB, DF, etc.) 98' NSL 6. Lease Designation and Serial No. ADL 22330 9. Unit or Lease Name KENAI BELUGA UNIT 10. Well Number KBU #13-8 1 1. Fie~d and Pool KENAI GAS FIELD 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] '- Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Welt [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.t05-170). The Sundry Notice submitted on 6/1/81 and approved on 6/2/81 for workover of thls well will not be used at this time. Please note that this workover has been postponed. 14. I herej;~ certify that th,/] foregoing is tr. ue and correct to the best of my knowledge. S,gne . _ _ / Title District Drlq Superintendent The z¥~'e "~el ow/r C~m m issi on ditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date 2/25/83 Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate February 16, 19 83 Union Oil Company of.California P.O. Box 6247 ' Anchorage, Alaska_9 9502 · Res ~Subsec. uent Reports, Sundry Notices and Reports on Wells (Form 10-403 ) For the following lists of "Notice of Intention To:" Sundry Notices and Report on Wells (form 10-403) this office does not have on record the "Subsequent Report of:" defining the action taken on the approved intention. Please advise this office by Subsequent ~eport of the disposition of the intention. Union Date Bri_ef De$.cri?_tion_:?_.f Intcnti.on TBU G- T~U G-89D TBU TBU A-1 iL TDU F~-4 PD GPS 33-14RD KBU 13-8 TBU D-9 TEUS C-27 TBUS G-6 TBU D-6RD ' TBU G-7 TBUS G-2 TBUS C.-3 K-1PD 10/1180 10/1/$0 10/1/~0 ~0/1/~0 1116180 2/11/81 6/1/~1 61£1e! 11/25/81 1/20/82 3/1815.2 412118-2 5/24/82 6/30/~2 7/14/82 Re~erferate C-3, C-4 Reperforate B-l, B-2, B-4 Reperforate B-5, B-i, B-4 ~cperforate Reperforate Perforate B zone Clean out, reu. erforate. Plug & abandon for sidetrack Pull tubing, reperforate Squeeze cement to abandon hemlock Change kickoff point Reperforate Revise setting abandonment retainer Repair casing Perforate LCSlJKT/glh STATE OF ALASKA ALASKA ~,.L AND GAS CONSERVATION CC.,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. UNION 0IL COHPANY OF CALIFORNIA 77-29 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50-733-20304 4. Location of Well 804'S & 675'W of the NE corner of Section 18, T4N, RllW, SM, 5. Elevation in feet (indicate KB, DF, etc.) 98' above HSL 6. Lease Designation and Serial No. ADL # 22330 9. Unit or Lease Name KENAI BELUGA UNTT 10. Well Number KBU #13-8 1 1, Field and Pool KENAI GAS FIELD 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). (See attachment) Alaska 0ii & Gas Cons. Commission A,chorage 14. I I~eby)ertify that th~.Oi/lg is true and correct ,o the best of my knowledge. Signed ~.~. ~'/~~~'~Z._~./,r~/~.~.~/ Title g~sz ~RLG SUPT. Th~below for Commission use Date 6/1/81 C_,~ad~ions of Approval, if any: Approved by ORIGINAl.' ~!GHE~f BY LJiitNiE l~. S~il~ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SUNDRY NOTICE KBU #13-8 It is proposed to clean out, reperforate and return to production KBU #13-8, Kenai Gas Field, as follows- 1. Move rig over KBU #13-8 and rig up. 2. Kill well, remove tree, install and test BOPE. 3. Pull and lay down existing dual 2 7/8" X 3 1/2" tubing string. 4. Retrieve prod. packer and clean out to +8700'. -- 5. Reperforate the Upper and Lower Beluga sands. 6. Treat the Upper Beluga sands with AL-OH. 7. Run and set production packer @ +_7463'. 8. Run dual 2 7/8" X 3 1/2" completion assembly. 9. Remove BOPE, install and test tree. 10. Place well on production. JUN .- 21,%'.i l~laska Oil & Gar, Oons. C°nm~issior~ l~chorage TO John A. LeVOrsen Dept. Natural Resources ^§23 E. 4th Avenue Anchorage, AK 99501 Document Transmit3~ L__._~__¢OMr'~..~ Union 0 ' Company of (/" ' niaJ ~a COMM ,. J, ~ CO~ · DATE SUBMITTED JAcco Nov. 28, 1979 .-- TRANSMITTING THE FOLLOWING: FROM S. J. Schreiber {ln'i nn Oi! C~_ny AT P.O. Box 6247 Anchorage, AK 9950~ TELEPHONE NO. 2550-9050' -. Please ackn~ledqe receipt by signing and returninq copy of document transmittal. Date: RECE!V :: OiJ ~, g*'~ (,,,{'i5. FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. Document Transmittal ,'i ~l~nion Oil Company of CaliforF~ia uni n DATE SUBMITTED I COMM__]~ April 20, 1979 · o ~ou '~1 RES ENG Bill V~ ~1~ R.C. W~~ / AT AT I 3 ENO , · E~E~O~ ~o. ~ 1 GEOL T~ANSM~TT~NO THE FOLLOWiNg: ~ 2G~ ...... i Dls~on~l ~e~ -' CONFER: F~LF: . Plebe accel ~A rani nf hv · ate: ~iv~: Z. "~v~"O FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. .Form N~,;. G-1 STATE OF ALASKA. OIL AND GAS CONSERVATION COMMITTEE Field Operator ('ounty Kenai Producing Thru I c o. TBG. Size 3 1/2" GAS WELL OPEN FLOW POTENTIAL TEST MuIL~-POINT TEST Initial ~ Annual ~ , ,- I Reservoir Kenai Gas Field I Union Oil Co. of Calif. I A-028142 Comple~ion .~_ DUPLICATE - · Pipeline Connection Nikiski Multiple Completion (Dual or Triple) Dual JLocation' 780'S & 7010'W of the NE Corner Secdnn 1~: T4N~ R!!W, S. J ~e ir" J Wdtheid J CSG, Size J .... ~,Vt/Ft. I.D. j j j jTemperature Temperature 105 'r 67 'r 9 5/8" 47 g 8.618" 216 3 1/2" 2.992" 5595' , 0.555 jType Taps Type production from each zone ,, OBSERVED Flow Data - , , es{ Date ..... ~ . : , J j~Vell No. l ~ I["} I imm: --i Set ~ Length (h) gallo M('F per Bbl. Liquid (Apl) 5595' 3105 Time J (Prover) i (Choke) Press. Diff. Tubing Casing Flowing No. of Flow[ (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig w pslg psig °I~ . .. s, :. 1 J 3.826 ~..5 165'6 3.24 1618 Packer 66 _,, "1t 3. 826 ' 2.5 . 1549 8.41.. 1527. Packer 67 ~. I 1 ! 3.826 J 2.5 lZ[11 1 a an 1387 Packer 67 ~' IIJ1 J3. 826 J Z. 5 J l 186 , ~1 i '~6 1.1 6~q p_:,-,t-~,,, r-,'7 FLOW CALCULATIONS , , Coeffi- Flow Temp. Gravity Compress. lhlo. cient h p Pressure Factor Factor Factor Rate. of Flow (24 Hr.) w m psta F F F q MCF/D t g pv ,. 34.15' j l'~3.58 1671 .994 J .1 342 I 0gq z. 34.15 114.69 1.564 .993 J 1.342 !.092 , 5700 ,~. 34.15_ 150.99 1425 .,993 j 1 '342 I : 088 7475 l ]l ' .... 34.15 , 194.07. 1201 .993J 1, $42 1. 075 9493 PRESSURE CALCULATIONS .. P P w Cal. w (psla) P'-' F Q (F q): (F Q)-~ X 1-e-~ P: p~ _ P: , p p :t c c c w c ,.v w P t c 1. , , , t Il , J ' I i , I J ' I I I Absolute Potential ii 13,700 .X~CF/D : 0. 675 CERTIFICATE: I, the undersigned, state that I am the Engineer of thelTnirm ('Ii! Co. of Calif. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to ' (B signature Alan D. Sharpnack g 0 t 77 Divisio~ 0t Oil ..&, ~,~ ~'~n~,r~rvCJon GAr ,,~ELL OPEN FLOW POTENTIAL TEST Ru, ORT PRESSURE CALCULAT I O;4S (Supplement to Alaska'O & GCC Form No. G-I) Field Kenai Gas Field Operator Union Oil Co. of California IReservol. r ' J Beluga ILease . A-028142 Tesf Da te ]]/8/77 _ _ Wet I ~io. KBU #13-8 S Test (I) (2) (3) (4) Ps Pf (Ps2 - pf2) Q No ~s~a ~si~ X 104 ~..,~F/D 1 1792 __, 1&33, . 54.46 3663 2 1806 1542 88.39 5670 3 1808 .1402 130.33 7434 4 1808 1180 187.65 9441 Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed. Cullender-Smith ~,~ethod of (I) (2) (3) (4) Test Pws 0 ' (Pws2-pw~2) Q No psia psia X I0 4 ~,~ ,~ .................. ....... ....... , . ..... ..... ~ ......... ] Nomenclature. Ps = Static surface pressure '-P-f~__= Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, I.',CF per day at 60°F and 14.65 psia RECEIVED W~'i1.'].' KB U #13-8 S Pool' Upper Beluga ,_ ~rvev Dal, e 11/8/77 1.0 ~.? 'LC., F ,/D Form ~E,,,~ t0-69 (- STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT MuIt;-POINT TEST Test Initial . [~ Annual [~ Special Field I Reservoir Kenai Gas Field Beluga Operator ! Lease Union 0ii Company of California /1-028142 County I Locati,,n 780' S a 700' W of N Corner Kenai t Section 18, T4N, RllW Producing Thru t Re~em. oir.. i Wellhead j CSG. SizeI ,Vt/Ft. t I~ °F u, .~ 9 5/8" 47 lb. Completion Date 9-28-77 ! .... ] DUPLICATE Total Depth- Test Date 11-3-77 %Veil No. KBU 13-8L T/Pay Pr,ducing 147 18 I.D. [ Set (g) 8.6]8" I 8769' [ Set @ I GasGra'ttr [ ^v"?r°rl' I GLI 75k6" 0.555 h188 Gas-Liquid Hydrocarbon Ratio MCF per Bbl. Gravily of Liquid (Apt) Pipeline Connection Nikiski 3Iultiple Completion (Dual or Triple) Dual Type Taps Flange Type production from each zone Gas OBSERVED DATA. Flow Data No. Time of Flow Hours (Prover) (Line) Size 3.826 3.826 (Choke) (Orifice) Size Press. psig Diff. h %v 1.75 1956 I ]_ ._h_4 1.75 1584 i 15.21 Tubing Press. pslg Casing Press. psig t936 1568 1290 1109 Packer Packer Flowing Temp. 'F 57 - 57 5_8 1 , 3.826 1.75 t lq12 J 28.09 1. ~.826 1.75 I 1134 i 42,25 '~9 FLO%V CALCULATIONS Floxv Temp. Gravity [ Compress. Coefft- "' Factor Factor Factor Rate of Flow No. cient --~hw P Pressure F F F Q MCF/D [ (24 Hr.) , m psla t g pv ,. [ 15.39 i 53.28 1971 1.003 1.342 1.121 1238 2. 15.39 155 95 1599 1.003 i 1.342 1.106 3573 15. ~9 192.34 I 1317 1. 002 i 1. 342 1. 091 4.3h4 4. 15. '~9 220.33) ~149 '1.00_2 i 1.. qb2 1 . 078 4911 _ , PRESSU RIg CALCULATIONS P p p~ p~ , Cal. w w (psia) P'-' F Q (F Q)~ (F Q)'" X 1-e-~ P: -- P - w e w w P' p :t C C C e t , · Absolute Potential Il 6200 .x~CF/D I 0. 825 ' . CERTIFICATE: I, the undersigned, state that I am thoEngineer of the Union 0il Co. · (company), and that I am authorized by said company to make this report; and that this report was pre- . . pared under my supervision and direction and that the facts stated therein are true, correct and complete to · knowledge. Signature Alan D. Sharpnack;\ GM. v'/ELL OPEN FLOW POTENTIAL TEST R~_,'ORT PRESSURE CALCULATIONS (Supplement to Alaska'O & GCC Form No. G-I) Tes? Date Field Kenai Gas Field R~serv°i'r Beluga 11-3-77 Operat~'r ........ Lease Welt '~o. Union Oil Company of California A-02 8142 K~U 13-8L . ,, Test (I) (2) (3) (4) Ps pf (ps2_ pt2) 0 No. 0~.La psi~ X I04 !..~CF/D i 2163 1951 87.22 12 31 2 2262 1583 261.08 3554 3 2263 1305 .341.81 4320 .. 4 2248 1124 379.01 4885 _ · 1-70 Sub-Surface Test Data Subsurface pressu#es measured. Subsurface pressures computed. Cullender-Smith ?tethod of tOCC. (I) (2) (3) (4) Test Pws 0 ( Pws2-pw ~ 2 ) O No Dsia psia X I0-4 '.'~ * "'L_,, /~i) ."-' · -.~ ~ ~- ':". .. ] ,. F ~ .... . ": ,".'. '~. · ............ Nomenclature- Ps = Static surface pressure '-Bt___= Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q ~ Flow rate '~ , I.,~F per day at 60°F and 14.65 psia Pre ,Ire KBU 13-8L Lower Beluga pal,~',: 11-3-77 1.0 .... rT"-- ......... : i .......... ', .............. t ...... t ..... ~___. ~. ~ _ ~___ ~___~ ......... ~_ .. ~ .._~ ...................... ~ .......... ~ ....... ~-- ~ ~---7 ' , · ~ ~ '~ ~ i ~ ~' ~/ ~ ~ / '1' ' ~ ' ' '-~~ ................................ ~ ...... ~ ..... ~ ............. ~__.~ .......... '-~- ~ ~ ~ ........... ~ ..................... ~ ..................... ~--~.~. + ~ ....................... :, ............ : -: ...... ;_..~---/~ .... ~J.__~._~_.~_: .... ~ .............. ~ ......... ; ....... [ .... ~ ....... ~ .... · ' ' i ~ i ' ' i ] I · ' · I: ~ . ~ : ~ I ..- ~ ~ ~ i~ - ' ! ! ':: ;' ' I ...10_, --/ ' ' ~--i~ .... 'i ..... :' .... ~ ..... ~ ........ ~ .... ~ i .O5 t i i ! I 1.0 10 20 .".; 0 10C OAS ?'LO'~? RATE 'e~rC~ D .... DocUment Transmittal union Oi'l Company of Call ia unlen . DATE SUBMITTED ACCOUNTING t~IONTH ].]./?/77 ii TO ' : FROM H. W. Kugler R.C. Warthen AT State Div. of Oil & Gas '1~.O. Box 6247 Anchorage, AK 99504 Anchorage, /~K 99502 .'_ ". TELEPHONE NO. TRaNSMiTTING the FOLLOWING.: . . KENAI BF, LUGA UNE 13-8: .,. . ...... 1 BL '& 1 Sepia of each · . 2" DIL w/Linear COrrelation Log 2" 5".. Sonic' .C~_~X~~xX~'\ ~, 2" FDC 5"' CN-FD 5"i.: DTL .: . , .. , , ,, FORM I-2M02 (REV. 11-72) PRINTED IN U.5.A. Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-20304 6. LEASE DESIGNA'FION AND SERIAL NO. ^DL 22330 2. NAME OF OPERATOR 8. ~JjNIT FArM OR_LEASE NAME Union Oil Co. of Calif. Renal Beluga Unit 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99~02 4. LOCATION OF WELL 804'W f 675'W of the NE corner, Section 18,.T4N, RllW, S.M. ~ ! ~ i:'. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 9. WELL NO. KBU 13-8 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC. T. R. M. (BOTTOM tiOLE OBJECTIVE) Sec 8 T4N, RllW, S.M. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 45 46 9/1/77 8770'TD tested Beluga interval #2 perfs 6790' . 9/2/77 7501 'ETD (junk on cmt. ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770 'TD 7501 'ETD (junk on cmt ret) 9 5/8" csg. @8769' 13 3/8" csg. @2505' to 7264' for 23 hrs. @min. rate of 1.5 MMCFPD plus 5.6 BWPH to max rate of 4.5 MMCFPD plus 3.2 BWPH. Total of 220BW recovered in 23 hrs for average water prod rate of 9.6 BWPH. Tested Beluga interval #2 lower perfs 6790' to 7264' for l0 hrs @ max rate of 4.9 MMCFPD plus 3.2 BWPH w/ 335 psi tbg. pressure. Average rate for 10 hrs of 4.6 MMCFPD plus 8.6 BWPH. Killed well and RIH to sand fill @7050' (451' = 185 cu.ft.) Washed out sand to 7275' and circulated to condition W.O. fluid. ~Set pkr @7144'. Broke dwn. perfs 7244'-7264' @2400 psi and pumped in @19 CFM & 2500 psi. Squeezed perfs 7244'-7264' w/ 100 sx Class "G" containing .75% D=31 and 1% CaC12 to a final pressure of 2900 psi. Reversed out and pulled up to 6700' Circ. & condition mud while WOC 3 hrs. 14. I her~ certify that the~:~:e~'is tru~ and correct -¢-~ ~'~(' Dist Drlu SuDt DAT~ 10/14/77 NOT~O~_~thls ~orm is required for each calend~r month, regardle~ of the st~us o~ operations, ~nd mu~ be ~iled in duplic~te with the oil ~nd ~s conserwtion :ommitt~ bv the 15th of the su~eedinB month,unl~ otherwise 48 9/3/77 9/4/77 8770 'TD 7501 'ETD (junk on cmt. ret) 9 5/8" csg. @8769' 13 3/8" csg. @2505' Set pkr @6926'. Broke dwn perfs 7~Z04'-7018' and 7040'-7076' @ 1°-3 psi and pumped in @ l~ CFM & o psi. Squeezed perfs 7~4'-7076' w/ 200 sx. C1 "G" containing .75% D-31 and 1% CaC12 to a final pressure of 2600 psi and bled off to 1500 psi in 1/2 hr. Reversed out and pulled up to 6676'. Circ. and cond. mud while WOC 3 hrs. Set pkr @6676'. Broke dwn. perfs 6790'-6804', 6820'-6845' and 6852'-6882' w/ 1500 psi and pumped in @19.5 cfm & 1900 psi. Squeezed perfs 6790'-6882' w/ 300 sx. C1 "G" containing .75% D-31 and 1% CaC12 to a final pressure of 3000 psi and bled off to 1500 psi in 1/2 hr. Revesred out and pulled up to 6250'. Circ. and condition mud while WOC 3 hrs. Pressure test squeezed perfs 6344'-6474' to .85 grad. and bled to .74 grad. and held. Moved pkr to 6676' and pressure perfs 6790'-6882' to .85 grad. Bled off to .74 grad. and held. Pooh. Ran 8 1/2" bit, 9 5/8" csg. scraper and 6 DC on 5" DP. 8770'TD CO squeze cmt 6678'-6930', 6950'-7080', 7238'-7313'. Washed 7501 'ETD out sand to 7501 'ETD and circ. hole clean. Pooh. Ran (junk cmt GO Int. CBL signature log from 7465' to 4000'. LD 5" re) HWDP. Ran 9 5/8" HOWCO RTTS pkr and APR valve on 2 7/8" 9 5/8" csg. 6.4# N-80 butt. tbg., incomplete. ~9 9/5/77 9/6/77 8770 'TD 7501 'ETD 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 7501'ETD (junk on cmt ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' Set pkr @6250' and pressured annulus to 1200 psi to open APR valve. Dry tested squeezed perfs 6344' to 7264' for 3/4 hrs. w/ only slight blow in bubble bucket. Moved pkr to 6750' and dry tested squeezed perfs 6790' to 7264' for 1 hr w/ only slight blow in bubble bucket and pressure loss from 1200 psi to 900 psi on annulus. Located tbg. leak and retested perfs 6790' to 7264' for 1/2 hr w/ only slight blow in bubble bucket. Reperf Beluga interval #2 lower perfs w/ 4 HPF using 2 1/8" torpedo jet-link expendable gun 6820' to 6840'. Checked F.L. @5350' in tbgo after perf (1400' = 45 cu.ft, entry). Gas rate too small to measure thru separator. Reperf Beluga interval #2 lower pers as above 7040' to 7076'. Gas rate still too small to measure. Pooh w/ tbg. to reperf w/ 4" csg. gun. Killed well and pooh. GO Int. reperf w/ 4 HPF using 4" DML 25 gm charge 7040' to 7076' and 6820' to 6840'. Ran 9 5/8" 'HOWCO test pkr and APR valve on dry 2 7/8" tbg. and set pkr @6750'. Opened APR valve @ll'O0 a.m. Flow tested well thru by pass for 2 hrs.w/ gas rate too small to measure. Shut in 1 hr. and pressure built up to 270 psi. Flow tested well thru by pass 4 hrs. @ very low gas rate. Flow tested well thru sep. for 6 hrs. Time Rate Water TP 7'00 240 MMCFPD 12.8 BWPH 3--~ psi 9-00 340 2.8 35 11'00 450 2.5 45 l?.O0 475 1.5 55 51 52 9/7/77 9/8/77 8770 'TD 6230'ETD (ret) 13 3/8" csg. csg @2505' 9 5/8" csg. @8769' 8770'TD 62 30 "ETD (cmt ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' Tested Beluga interval #2 reperfs 7040' to 7076' and 6820' to bu,u for l0 hrs at max rate of 1.9 MMCFPD plus .8 BWPH. Killed well and RIH to fill @7402' (suspect sand = 41 cu.ft.). Could not clean out fill w/ test pkr. Circ. btms. up and pooh. GO Int. set 9 5/8" cmt. ret. @6230'. Removed 12" 3000 psi BOPE to replace w/ 10" 5000 psi BOPE. Finished removing 12" 3000 psi BOPE and NU 10" 5000 psi double gate Shaffer and 10" 5000 psi hydril. Tested BOPE to 3000 psi. Ran 9 5/8" HOWCO test pkr and APR valve on dry 2 7/8" tbg. and set pkr @5592'. Opened APR valve w/ llO0 psi on annulus. GO Int. perfed Beluga Test Interval #3 w/ 4 HPF using 2 1/8" torpedo jet link expendable gun 5658' to 5694'. Tested well for 4 hrs. @ max rate of 7.4 MMCFPD plus .3 BWPH water. 53 54 55 9/9/77 9/10/77 9/11/77 8770'TD 6230'ETD 13 3/8" csg@2505' 9 5/8"csg @8769' 8770'TD 6230'ETD 13 3/8" csg@2505' 9 5/8" csg. @8769' 8770'TD 6230'ETD 13 3/8" cs9@2505' 9 5/8"csg csg@8769' With 9 5/8" cmt. ret @6230' and 9 5/8" test pkr set @5592' on 2 7/8" tbg. GO Int, cont. perf. Beluga test interval #3 w/ 4 HPF using 2 1/8" torpedo jet link expendable gun @5752' to 5770'. Tested entire Beluga interval #3 perfs 5658' to 5770' for 5 1/2 hrs. @ max rate of 8.5 MMCFPD plus 0 BWPH w/ 455 psi TP. Ran perf gun to perf. next interval and gun hung up in 2 7/8" tbg. @1850'. Pulled gun in two. Killed well and pooh w/ tbg. Ran 9 5/8" Baker retrievamatic pkr & stimulation valve on dry 5" DP and set pkr @5600'. Opened valve and flow ell to clean up for 2 3/4 hrs. @ max. rate of 9.8 MMCFPD plus 0 BWPH w/ 940 psi TP. Ran perf gun to perforate next interval and could not get thru stimulatio~ valve. Killed well and pooh w/ DP. Ran 9 5/8" HOWCO RTTS and APR valve on 5" DP and set @5593'. Openen valve and flow well to clean up for 2 1/2 hrs @ max rate of 7.3 MMCFPD plus 1 BWPH w/ 380 psi TP. GO Int. cont. perf. Beluga test interval #3 as above @5804' to 5830'. Tested entire Beluga interval #3 perfs 5658' to 5830' for 5 1/2 hrs. @ max. rate of 13.3 MMCFPD plus 3.2 BWPH w/ 880 psi TP. GO Int. cont. perf. Beluga test interval #3 as above @5872' to 5912'. Tested entire Beluga interval #3 perfs 5658' to 5912' for 14 hrs @ max rate of 15.75 MMCFPD plus 5 1/2 BWPH w/ 900 psi TP. Recoverd 72 BW in 12 hrs (4 1/2 BW rathole volume) for avg. of 6 BWPH. Killed well and pooh w/ DP. Ran 9 5/8" HOWCO cmt ret on WL and stuck ret @5872' in perfs. 5872' to 5912'. Ran stinger on 5" DP and tested ret @5872' w/ good circ. Pooh. Ran 8 1/2" RR bit #10 and 9 5/8" csg. scraper on 5" DP and drilled out ret. Pushed ret to 6230'ETD and circ. hole clean. 56 57 9/12/77 9/13/77 8770 'TD 5845'ETD (cmt ret) 1 3 3/8" csg@2505' .. 9 5/8" csg@8769' 8770'TD 6220' ETD (junk on cmt ret) 1 3 3/8" Finished circ. hole clean @6230'ETD and pooh. Ran 9 5/8" Howco cmt. ret. on W.L. and set @5845'. Ran stinger on 5" DP and pumped in Beluga test interval #3 perfs 5872'-5912' @17CFM & 1950 psi. Held 650 psi w/ pump off. Squeezed perq 5872'-5912' w/ 250 sx. Class "G" cmt w/ .75% D-31 and 1% CaC12 to a final pressure of 3000 psi. Press. bled to 2600 psi and held. Pulled out of ret. and pooh. Ran 9 5/8" How( cmt ret, on W.L. and set @5774'. Ran stinger on 5" DP and pumped in Beluga test interval #3 perfs 5804' to 5830' @17 1/2 CFM & 2300 psi. Held 700 psi w/ pump off. Sqz. perfs 5804' to 5830' w/ 250 sx. C1 "G" cmt w/ .75% D-31 and 1% CaC12 to a final pressure of 2500 psi. Press. bled to 2000 psi and held. Pulled out of ret. and pooh. Ran 8 1/2' RR bit #10 and 9 5/8" csg. scraper on 5" DP to 5600' and WOC total of 5 hrs. Drilled cmt ret @5774' and hard cmt. to 5830'. Washed to ret @5845' and now drlg on cmt ret. Drlg on ret @5845' 2 hrs w/ RR bit #10 and pooh for new bit. Ran bit #11 and 9 5/8" csg. scraper on 5" DP and drlg ret @5845' and hard cmt to 5878' in 7 1/2 hrs. Pooh and ran bit #12 and 9 5/8" csg. scraper on 5" DP. Drlg hare cmt to 5920' and washed to junk on cmt ret @6220'. Circ. he clean and cond. mud. Pooh. 58 59 9/14/77 9/15/77 8770'TD RIH . Set Howco pkr @5780' for dry test. Formation taking 6220'ETD fluid thru Perfs @5752' to 5770' & 5658' to 5694' Could not (junk on dry test. Pulled back to 5598'. Set Howco pkr, ~pened Howco cmt ret) APR valve. Put well on test. Started testing upper Beluga 13 3/8" perfs 5658' to 5694' and 5752' to 5770'. Well cleaned up csg@2505' ll MMCF/day - no water cut. Shut in well - final rate 9 5/8" 12.125 MMCF/day - no water cut. Perf upper Beluga 6142'- csg@8769' 61481DIL w/ 4 HPF using GO Int. 2 1/8" trpedo jet-link expendable gun under drawdown conditions. Put well back on test at 3:00 p.m. Rate at 6:00 p.m. 13.5 MMCF/day no water cut. Water cut started back up & rate decreasing. Rate at 12:00 p.m. plus or minus 12.0 MMCF/day - 4 BWPH. 8770'TD Prod tested Upper Beluga test Int. #3. Perfs open 5694'- 6220'ETD 5698', 5752' to 5770' (perfs not showing on log) and (junk on 6142' to 6148'.. Prod. test at 13.75MMCF/day - 29 BWPD. cmt ret) Added perfs 6092' to 6098'. Tested at 15.5 MMCF/day 13 3/8" 14.4 BWPD. Reperf 5755' to 5765'. Rate increased 18.1 csg@2505' MMCF/day - 14.4 BWPD. 9 5/8" csg@8769' 6O 61 62 9/16/77 9/17/77 9/18/77 8770'TD Flow tested for 7 hrs Beluga test interval #3 perfs 5658'-5694', 6975' ETD 5752' to 5770', 6005' to 6025', 6092' to 6098' and 6142' to (cmt ret) 6148' @ final rate of 17.5 MMCFPD plus 0 BW w/ 1120 psi DP 13 3/8" press. Shut well in for 1 hr and pressure built to 1560 psi. csg@2505' Killed well and circ. to condition W.O. fluid. Pooh. Ran 9 5/8" 8 1/2" bit #13 on BHA #15 and drilled out cmt ret @6230 and csg@8769' 7509'. CO 9 5/8" csg. to cmt ret @8245'ETD and circ. to cond. W.O. fluid. 8770'TD Pooh. Ran Howco 9 5/8" RTBP and RTTS test pkr on 5" DP and 6975'ETD set RTPB @7113' w/ pkr @ 7020' to straddle Beluga test (cmt ret) interval #2 perfs 7040' to 7076'. PI perfs for hydroxy 13 3/8" aluminum sand control squeeze @ 1 1/2 CFM & 1850 psi. Started csg@2505' sand control squeeze pumping 1470 gal 15% Hcl, 2940 gal 5% 9 5/8" KC1, and 847 gal hydroxy aluminum. With 276 gal 15% HC1 csg@8769' into formation had upward communication to squeezed perfs 7004' to 7018'. Rev. out and moved RTTS pkr to 6980' to straddle squeezed perfs 7004' to 7018' and open perfs 7040' to 7076'. Cont. sand control squeeze and had upward communication to perfs group between 6790' to 6882' (squeezed & reperf @6820' to 6840') w/ 1386 gal 15% HCI in formation. Ran in to RTBP @ 7113' and circ. btms up. Retrieved RTBP and pooh. 8770'TD Set 9 5/8" Baker cmt ret on W.L. @7325' and 6975'. Ran stinger 6975'ETD on 5" DP to ret @6975'. PI Beluga test interval #2 perfs (cmt ret) 7040' to 7076' (and squeezed perfs 7004' to 7018') @ 15 CFM 13 3/8" & 2000 psi and had upward communication to perfs group 6790' csg~2505' to 6882'. Pumped and rotated out of cmt ret @6975' w/ 75,000# 9 5/8" above string wt. Circ. hole clean and rec. fine formation csg@8769' sand. Pooh. Ran 9 5/8" RTTS pkr on 5" DP and set ~6754'. PI perfs 6820' to 6840' (6790' to 6804' and 6852' to 6882' squeezed & not reperf @ 16 CFM & 1900 psi. Held 800 psi w/ pump off. 'Squeezed Beluga test interval #2 perfs 6820' to 6840' (and squeezed perfs as above) w/ 300 sx. C1 "G" cmtw/ .75% CFR-2 & 1% CaC12 to final pressure of 3200 psi ~1 1/2 CFM. Bled to 2400 psi & held. Released pkr and pooh. Ran 8 1/2" bit #14 on BHA #15 on 5" DP and WOC 5 hrs. Drlg cmt. from 6537' (217' = 89 cu. ft. bleed back) to 6641' 63 64 65 66 67 68 6/19/77 9/20/77 9/21/77 9/22/77 9/23/77 9/24/77 8770'TD 13 3/8" csg @2505' 9 5/8" csg. cst@8769' Drlg cmt 6641' to 6880' (base of sqz perfs). No cmt from 6880' to top of ret at 6975'. Drlg cmt ret at 6975'. No cmt to ret at 7325'. Pooh. Ran sqz. tool & set at 6975'. Broke dwn. perfs 7004' to 7018' and 7040' to 7076' at 2250 psi - 15 cu.ft./min. Formation held 1200 psi w/o pump. Sqz. perfs w/ 200 sx C1 "G" w/ additives to a final press of 2800 psi. CIP at 12:20 p.m. Pooh w/ sqz. tool. Ran 8 1/2" bit & scraper. Tagged cmt. 6881'. Drlg cmt. from 6881' to 7071' (base of perfs). Bit torqued. Pooh. Lost 2 bolts off of Baker csg. scraper. LD scraper. 8770'TD Completed TIH w/ 8 1/2" bit. Tagged cmt. @7071' Drlg 8245'ETD(ret) firm cmt to 7150'. CO (no cmt) to ret @7325'. Drlg ret 13 3/8" csg & CO to ETD @8245'. Pooh w/ bit & ran 2 7/8" tbg in hole @2505' & pooh laying dwn same. RU GO Int. Ran W.L. gage ring - 9 5/8" csg. unable to get below 6200'. @8769' 8770'TD Could not work 8.5" od gage ring below 6200' w/ W.L. Pooh 8245'ETD(ret) and RD W.L. tools. Ran 8 1/2" bit #14 and 9 5/8" csg. 13 3/8" csg. scraper on 5" DP to 8245' ETD and circ btms up. Pooh. Ran 9 5/8" csg. 8.5" od gage ring on W.L. and could not work below 6343'. @2505' Ran 8.25" od gage ring on W.L. to 7500'. Set Baker 9 5/8" x 4 3/4" Model D pkr on W.L. @7450'. Ran Baker seal assy on 5" DP and tested pkr @7450' to 1000 psi. Pooh and LD 5" DP. 8770'TD Finished pooh and LD 5" DP and seal assy. RU casing crew 8245'ETD(ret) and began running 2 7/8" 6.4# N-80 Armco seal-lok long string 13 3/8" csg @2505' 9 5/8" csg. @8769' tbg. Ran dual 2 7/8" long string and 3 1/2" 9.2# N-80 butt short string tbg. to plus or minus 3550'. Circ. from 3550' and raise mud wt to 72# to pooh. Pulled dual tbg. strings. Changed out defective OCT 13 5/8" 5000 x 10" 5000 psi tbg. spool for CIW 12" 3000 x 10" 5000 psi DCB tbg spool. Clean and sort scaled and rusted 2 7/8" tbg. 8770'TD 8245'ETD 13 3/8" csg @2505' 9 5/8I' csg @8769' Finished cleaning and sorting 2 7/8" tbg. Ran 2 7/8" Armco seal lock 6.4# N-80 long string and 3 1/2" 9.2# N-80 butt short string tbg. 8770'TD 8245'ETD Spaced, out & landed long string in Baker M,odel D pkr @7450 w/ Baker single hydraulic p_kr.[a6.232~: Space~d~gu~l~ 69 9/25/77 13 3/8" csg @2505' 9 5/8" csg. @8769' 8770'TD 8245'ETD 7450'Baker Mod D pkr 13 3/8" csg @2505' 9 5/8" csg. @8769' string. Ran "X" plug and stuck in "XA" sleeve @7418'. Jarred on plug w/o success. Cut W.L. and ran fishing tools w/ new jars. Jarred on plug w/o success. Cut W.L. and RU braided W.L. unit. Made 3 runs w/ fishing tools and recovered all W.L. tools. Left "X" plug in "XA" sleeve @7418'. Set Baker single hydraulic pkr @6232'. Ran "XN" plug in short string and set in "XN" nipple @5577'. Set Baker dual hydraulic pkr @5579'. Retrieved "XN" plug from short string. 70 71 72 9/26/77 9/27/77 9/28/77 9/29/77 8770'TD Ran W~L. tools and attempted to retrieve "X" plug @7418' in 8245'ETD(ret) 2 7/8" short string. Retrieving tool not holding latch. Ran 7450'Baker 1 1/2" - 1 7/8" bailer and cleaned out scale on top of plug. Mod D pkr 13 3/8" csg csg@2505' 9 5/8" csg @8769' Re-ran retrieving tool w/o success. Ran 2 1/4" bailer and 1 7/8" bailer to clean out scale on plug. Re-ran retrieving tool w/ no success. 8770'TD Ran W.L. bailer and cleaned out scale on top of X plug @7418' 8245'ETD(ret) in 2 7/8" long string. Ran spear and hydraulic jars on W.L. 7450'Baker Mod D pkr 13 3/8" csg. csg@2505' 9 5/8" csg @8769' and engaged plug. Jarred plug out of ×A sleeve and sheared off W.L. tools. Pumped down long string and pumped X plug out end of tbg. Installed CIW back pressure valves in tbg. and ND BOPE. 8770'TD 8245'ETD 7450' Baker Mod D pkr 13 3/8" csg. csg@2505' 9 5/8" csg. csg @8769' Finished ND BOPE. Installed CIW dual 3 1/2" 5000 psi X mas tree and pulled BPV. Rigged Otis W.L. unit and opened ~XA" sleeves @5582' in long string and 5499' in short string (dual hy pkr @5538'). Connected gas from #41-18 to tbg. strings and blow down to plus or minus 3200'. Closed sleeve in short string and flowed well to clean up thru short string while injecting gas thru long string. Closed sleeve in long string. Now flowing both short and long strings to clean up. Released rig @12:00 mid 9/28/77. II II Rigging down and moving out Brinkerhoff Drilling Co. Rig #59. Continued production testing long string tbg. on Lower Beluga zone perfs - rate increasing. Present rate 2.65 MMCF/day - no water - 130 psi tbg. press. Tested short string tbg. on Upper Beluga zone perfs. Present rate 10.5 MMCF/day - no water - 1200 psi tbg. press. KBU 13-8 - Perfor~=~'~i__~~s MD Tyonek 8660'-8680' 8334'-8364' Beluga #1 8202 7892 7840 7776 7731 7672 7642 -8218 -7916 -7865 -7812 -7751 -7680 '7662 7578 -7628 Beluga #2 7244 * 7040 7004 6852 ** 6820 6790 6466 6446 -7264' -7076' -7018' -6882' -6845' -6804' -6474' -6458' 6344 -6384' Beluga #3 6142'--6148' 6092'-6098" 6005'-6025' 5872'-5912' 5804'-5830' 5752'-5770' 5658'-5694' Zone Isol ati'on 8308'-8310' 7568'-7570' 6298'-6300' 5658'-5660' 5398'-5400' 5058'-5060' 4820'-4822' TVD (20') (3o') 7566' 7254' (16) (24) (25) (36) (20) (8) (20) (50) (2O) (36) (14) (3o) (25) (14) (8) (12) (40) 7119 6826 6776 6721 6671 6610 6587 654O 62O9 6023 5978 5842 5809 5776 5470 5453 5372 (16 (26 (38 (40 (26 (18 (36) ) 5176' ) 5128" ) 5057' ) ..... ~' 4944' ) .... 4878' ) 4829' 4752' Remarks Open but isolated below cmt ret @8245' Open and producing II II II II II ~q.z. w/ lO0 sx C1 G cmt w/ additives Sqz. w/ 200 sx C1 G cmt w/ additive.q S~z. w/ 300 sx Cl G cmt w/ladditives Resqueezed w/ 200 sx C1 G cmt w/ additives ~ Open & producing Open & producing Open & producing Sqz w/ 250 sx. C1 G cmt w/ additives Sqz w/ 250 sx C1 G cmt w/ additives Open & producing Open & producing Sqz. w/ 150 sx C1 G cmt w/ additives Sqz. w/ 150 sx C1G cmt w/ additives Sqz. w/ 200 sx C1G cmt w/ additives Sqz. w/ 200 sx C1G cmt w/ additives Sqz. w/ 200 sx C1G cmt w/ additives Resqueezed w/ 300 sx. C1G cmt w/ additives Sqz. w/ 150 sx C1 G cmt w/ additives Sqz. w/ 200 sx Cl G cmt w/ additives * Reper~orated. 7040'-7076',' ** Reperforated 6820'-6840' (36') (2o') Sqz. w/ 200 sx C1 G cmt w/ additives Sqz. w/ 300 sx C1 G cmt w/ additives Union Oil and Gas D :on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union October 12, 1977 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' KBU 13-8 KENAI GAS FIELD Dear Mr. Gilbreth' For your information enclosed are two (2) copies of the Well Completion Report for the above captioned project. Si ncerely yours, ',q... ., "~.J_~.Eb~R. C a 11 e n d e r "~' Dist. Drlg. Supt. sm cc. Marathon Oil Co. Division of Lands H.'. C. Lee STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* W E 1,I, mx' ELL DR Y Other b. TYPE OF COMPLETION: N?;w ~ Wt,IIK ~ DEEP- ~ PLUG ~ DIFF. ~ w EI,I, OVER EN BACK RESVR, Other ~ SUBMIT IN DU~ Zi , E* (Seegther In- St r~lctioBs Orl reverse side: 2. NAME ()F OPgRATOIt Union 0il Co. of Calif. 3. AI)DaEs8 OF OPERATOR P. 0. Box 6247~ Anchorage. AK 99502 4. Loc,,'rmx u~' WELL (Report location clearly and in accordance with any State requirements)* At surface 804'S & 675'W of NE corner of Sec 18, T4N, RllW, S M. .. .~ ~,,~, p~od. ~.~.~ ~,po~t~ ~ow 1745' N' &' 4t 0' E of SW corner of Sec 8, T4N, RllW, S.M. At total dep~ 2655'N & 902'E of SW corner of Sec 8, T4N, RllW, S.M. -5. API NUMERICAL CODE 50-133.-2.0304 6. LF_.ASE DF2xlGNATION AN~D SERIAL 1MO. 7. IF INDIA.N, ALLOTTEE OR TRIBE NAM~ 8. UNIT,FAiR2VI OR LF~kSE NAME k:onai gol~ga Unit 9. WELL NO. KBII 13-8 10. FIELD A2qD POOL, OR WILDCAT Kenai C,a.q Field 11. S~C., T., II.., iVI., (BOTTO!VI OBJI/iCTIVE) Sec 8, 14N, RllW, S.M. 12. P~-~R2VIIT 1~o. 77-29 / / ~OW~Y* l( ROTARY TOOLS~ [ CABLE TOOI.,8 ~'TMD 7664'TV~824B'MD 7!S2'TVD .-1 2 r ' T ~. PIIODUCING ~NTEHVAL(S), OF THIS CO.~P~TIO~TO,P, BOSOM, ~A~ (~D A~D ~)~ 122. SVA8 D-RECTIONAL ~ SURVEY MADE 7578~ TMD 6.51.5'TVD Long String Beluga Interval ~1 8218' TMD 7126"TVD . i Ye~ 24. TYPE I.;[,T,}CTi:I(7 AND OTIlE~ LOGS RUN DIL, GR-CNL, BHC Sopic Mud, lo~s from 2505' to ID , ,,,~. ~ ,, i CASING RECORD (Report all strings set in well) '13 3/8" 61~" -55 2505'. 1 1/~"i~4nn 9 5/8" 47~ ] N-80I 876q'_ l_ !74" 3000 sx C! G w/ additi 26 LtNEX BZCO~ ~ 27. (UBING 12 7/8" 7505' 7450' ' i I ii I i . i D~WTTi 1NT~V.~ (MD) [ AMOUNC ~D I'2!ND OF MA~EF~AL US~ See Attachment g2 See Att chment ~2 i i lit i i ii ii i DATE I,'il~>;'U ['t:.ODUCTiON [ P~ODUC'P](~" ?,)T,;I [~OD (Flov:i~g, ga3 lif~, pumping--size and type of pump') 9/30/77 ,) Flowing o/:/77 < I : - I 13000 I o I -- ..... i~5~~ ]CASI. NG PRffSsuRE ICALC~T~ OI~BBL. GAS--?XCF. WA~--BBL. [OIL GRAVITY-~I (CORR.) 5'd'~':'~' I 0 j~-~~ [ 16000 31. tqsPoS~TmN or oas (Sold, used for fuel, vented, etc.)' JTEST WITNESSED BY t Vented 32.LIST OF ATTACHMENTS #l short string product]on record ..... :';2. I h.reby cerpfl'q ,.hat the~or~in~ .nd attached information t. complete and correct as determined from all;available records (/ SI(;NEI,~~,_ TITLBDist. Drlg. Supt. DATE10~/77 // *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16,: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. O Items 20, and 22:: If this well is completed~:for separatc prcdb~ction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce~, show- ing the additional data pertinent to such interval. It~m]~: "S~cks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item ]8: Submit a separate completion report on this form for each interval to be separately produc~i. (See instruction for items 20 and 22 above). ' ;14. SUMMAlr~Y Ob" FORMATION T]F..STS INCLUDIN(; INTERVAL TESTED, P~URE DATA ~~'OV~l~ OF OIL, OAS. 35. G~GIC MA~K~ WAT~ AND MUD Fyonek 8334'-8364' Flowed 9 max rate 162 MCFPD w/ 55 psi tbg. press. . ~,r~s: ~ ~v~.,~.~. 8660'-8680' A-8 Sand 4330' 3649' A-9 Sand 4389' 3695' ~eluga Interval f2 (see attachment) A-10 Sand 4436' 3731' 6344'-7264' Flowed 9 max rate 3.4 MMCFPD plus 576 BWPD w/ A-11 Sand 4528' 3803' 350 psi tbg. press. B-1 Sand 4620' 3876' B-2 Sand 4684' 3927' 6790' -7264' Flowed 9 max rate 4.6 MMCFPD plus 206 BWPD w/ B-3 Sand 4759' 3987' 335 psi tbg. press. B-4 Sand 4840' 4052' B-5 Sand 5062' 4234' 7040'-7076' & Flowed ~ max rate 1.9 MMCFPD plus 20 BWPD w/ 80 psi C-1 Sand 5403' 4520' 6820' -6840' tba Dress. . C-2 Sand 5569' 4662' ~. co~ ~. ~. ~m~ ~m~o~s o~ ~,~o~o~. ~o~o~. ~~ ~~. ~,~ Top Beluga 5659' 4740' AN~ Dg'~EI) SHOWS OF OlD. , ,, Top Tyonek 8328' 7233' 75-8 Sand 8664' 7560' NONE SUBMIT IN DL,'LiCATE* STATE OF ALASKA ~ s~,,.th~r n~ l'ever~e side OIL AND GAS CONSERVATION COMMITTEE i i i WELk COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE 0F W~LL: OtL 6~s ~ WELL WELL ~ DRY Other b. TYPE OF COMPLE~ON: NEW ~ WORK ~ DEEP- ~ PLUG ~ DIFF. ~ WELI, OVER EN BACK gESVR. Other 2. NAME OF OPERATOR Union Oil Co. of Cali,f. 3. ADDRESS OF OPERATOR P. O. Box 6241. Anchnraae. AK 99E07 4, LOCxTION OF WELL (Re~ort location ¢~early ~n~in accordance with any State requirements)* At su~ace At top prod. interval reported below At total depth 13. D-a~TE SPUDD.EAD [14. DATE T,D. RF_,ACHED [15. DATE COMP SUSP OR ABANT). 18. TOTAL DEPTH, ~LD & TVD~19'[ PLUG, BACK MD & TVD~0. IF 1ViULTIPLE COMPL., 21. 1 I-IOW IVI~Y* ROTARY TOOLS 22. PRODUCING INTERVAL(S), OF THIS CO.NIPLETIOI~T--TO~P, BOTTOM, NAME (MD AND TV'D)* Beluga Interval #3'5658'TMD 4740'TVD Short String 6158'TMD 5183'TVD 5, API NU1VLEH/CAL CODE 6, LEASE DESiGNATiON A/ND SEi%LAL NO. 7.IF INDIA.N, Ai~LOTTEE OR 'i'HIBE NANLE 8.UNIT,F~IL1Vi OR LEASE NAME 9. WICI.L NO. KBU 13-8 10. FIELD &ND POOL, Oit WILDCA. T Kenai Gas Field 11. SEC., T., It,., M., (]3OTTOM t-{OLE OBJ EC'i'iVE) 12, PI~I~IIT NO, 16. ELEVATIONS tDF, RKB, t~T, GR, r~FC)*]17. ELEV. CASINGttEAD ,, INTERVAI,S I)ItlI.I,ED BY ----- CABI,E TOOl.t4 2'3. ~,VAS I)!RECTIONAL SUII¥'EY MADE I 24. TI'PE ELECTRIC AND OTHF_,Aq, LOGS RUN CkSI24G SIZE CASING REcoRD (Report al~ strings set in well) \VEIGIKT, LB/PT. DEPTH SET (1VID) HOLE SIZE 26. LINEX E/EC OitD 28. PERFORATi/ONS OPV~-ZNI TO PRO]DUC'lION' (h~tcrval, size and number) 30. DATE FIRST PIIODUCTION __9~0/7 7 ...... 10/_]Z77 PLO\V, TLT tBI tN~ G 2O0 ,'il. DISPOSITION OF Sold 12 [ 1" ' i1 PRODUCTION PI%ODUCTION M.EI[iOD (Flowii~g, L~.a3 lif~, pcnnping--size and type of Dump) Flowinq CASLNG PRESSURE [CALCULATED OIL---BBL. t 24 -I-IOU1-4 RP~TE ~AS (Sold, use[l /or fuel, vented, etc.) CJ~MLNTING RECOILD 27. TUBING tlEC O H,I) i A_Z4OUNT PULLED 32. LIST OF ATTACHMENTS SC~2EEN (~{D) SIZE ,3 1/2" 5572' ' 5538' 29. ACID, Si:OT, bq~/~f]'l UHE, CE,_'~if].NT SQU~5]Z~, ETC. D~'T~i INT~V.~ (MD) ~ ~MOUNF A~D I<IND OF AIA'/'~YllAL USED .... -.. i il i i i i DEPTI-t SET (MD~ ~ F'ACIiEI~ SET (MD) OIL--~BBL. I 1 GAS--MCF. I lO:Soo IV, ELL :YI?ATUS I Producing or Shut.j...n Vd//I'EI%~I3P, L. [ G~S-OIL ll.kTIO I o --- WATER--BBL. I OIL GIIAVITY-~I (CORR.) EST WITNESSED BY 33. I hereby cotc% that the forego~l,qg and attached information is complete and correct as determined from all-av,'tll,qble records *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct ,,,veil completion report end log on all types of lan:ts and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showr:) for depth measure- ments given in other spaces on this form and ~n any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state ,n item 20, and in iteq~ 22 show the prcJucir:9 interval, or. intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce.d, show- ing the ack:litional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each nterval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TE~'I'S IN('I_,UI)IN(; INTERVAL TESTED. PttESSURE DATA AND RECOVERIE,S OF OIL. GAS. 35. GEOLOGIC' WATER AND MUD , , NAME ~.~E^S. . ~ ~ , ~ ~ , ~ ,~ ir-' · · ~N~D :~tltECTEI,) SHOWS OF OIL, G&S :OI1 WA~I. '1 ,,~, ,, ,,,, Ub!:'O?q OiL CO. Oi'- C,':':L. IFO ..,., :A VVtZLL .E,H .'--i;:'T A PAGE 1"!0._ - ,, ~ KENAI BELUGA UNIT L,,'~A.So ?£.3_r,D KENAI GAS WELL NO. 13-8 . ,-...,~., .v 805' ' ~,O~..].IO'~, .S & 675 W.of NE Corner of Sec. 18, T4N, RllW, S.bi. .?ZF',?',!IT NO 77-29 T.D. 8770' MD SERIAJ= NO._ADL 22qqO ~ T.V.D. 7664 VD SPUD DATE 7/19/77 _ COMP. DATE 9/_28./_7_7 ...... CO?,!TRA. CTOR BRINKgRHOF3'__ __ P,.IG NO._.59_ TYPli; UNIT OILWELL 8_60 . DRILL PlPg DESCD, IPTION_SJL_E_a~~5 ELEVATIONS: WATER DEIzI'iI R.T. TO OCEAN FLOOR ~. T. TO MLL\V DEV!ATIO~ (BSi. L.) 71_01'S & 8983' W.' of Surface IR.T. TO DR'[I.L DECK · . .... -, - 18 9' ~, . IR. I% ro PROI),UC rIQN ,Ii,E..~K/~ .. · -. ,, ............ COMPANY ENGINEER_ ttESS..&..yZEK- ' APPROVED: ~-"~2.,,/~%f4/~'~./J~~/fr'f~-~'t'~z/-~t/ .":7-' " CASING'&: TUBING .P, EUORD SIZE 20" 13 3/8"} 61~/ i 9 5/8" 1 47~. ' { 9.2~J 2 7/8" ] 6.4~; . THEE.AD DRIVE BUTTREES BUTTRESS BUTTRESS BUTTRESS PIPE ......."' K-55 N-80 N-80 ~ N-80 / DEPTH 114' 2505' 8769' CMT'D THRU SHOE W/1200 SXS "G" W/GEL AND 200 S×S "G" NEAT. CMT'D THRU SHOE W/3000 SXS "G" W/ADDITIVES. 7446' L.iS. 7135'. of 2 '7/8" 5595' S.S. 5595' of 3 1/2" ~r, T-, ~ T ' P,'-R:' OR~TZ'I'G RECORD 311' of 3 1/2" 8/10/77} 8308-8310 8726' F.C. " 17568-7570 " " " 16298-6300 " " " 15658-5660 " " " 15398-5400 "' " - 8/11/7715058-5060 5630' cmt.. " " 14820-4822 " " 8/t,8,/77i8660-8680i8334-8364 ~/:,.,.~ 8i5.0..-'.;,;t' .FJ'L~' PK~.'i ~ROD. TEST '8/20/7717578-7628 ~- · 82_'45' Ret:. [ " · II 'I Il Isoaltion Sc -~7~1--777 i8202-8218// ""-" j7892-7916 ,, .. i7840-7865 -8/"/-2777] 7776- 7'812 " !76f2-7680 PROD. TEST' 8/24/77 16344-6384 7509' Ret. ' SQZ'D..W~150 SXs. SQZ'D W/200 sxs. · SQZ'D W/200 SAS. SQZ'D W/500'sxs. SQZ'D W/150 sxs. SQZ'D W/~00 sxs. ' "TYONEK" ZONE%. OPEN_B~ISO_L~_~E~ MECHANICALLY "TYONEK" ZONE~4/RET SE~_~45' '"BELUGA" ZONE OPE~_~QJt_~. "BELUGA" ZOR~ ,, - " " ' -- . !1 II Il II II 11 11 11 II II II 11 II II II II II Il Il Il l: Il " 17642-7662 : " " " " " " " II Il " SQZ'D W/450 sas. DATE [ I:;TERVAL ii7~77~ BELUGA il/8/7~ BELUGA T~p~:v - OCT .~ND CIW INITIAL PZOBUCTiOI'[ 1109 .' ] ', 1165 ~V ~L.L_ ttg~ D__2%S. DZJl, I c~m+:zl z.~cz.! ~o~ -! 4900! I 9710t 1. li-n~ GAS WELL GAS WELL CASING HEAD:. 20" 2000 psi x.2o" s_o.W- o:C:T: . '*~ .... X 1.3 q/g" 'lc 71" 17" CASIR'G ~:~.:,,C:.,.R:20" ' ~, Yq q/2" CASING SPOOL: 20" 2000 psi X 13 5/8" 5000 psi . . ,'""' i, ,, - -~-- ~ 12I' . · ~uBtNG ;.m::D: 3000 psi X 13 5/~" 5000 psi DSA on 12" '3006 psi X 10" 5000 psi "DOB" C I.W · ' ' i t ]7 '[ DUAL 3 1/2" "DCS" (EUEiUP BUTTRESS DOWN) TUBt~,GX' IIANGER: ~,~ ~ ~, ~ . ~ . . ~.. ~ ~ 10" TUBING llEAD TOP' 5000 psi ?J.A ST ER VALVES' 2-ea. 3" FULL BORE blASTER & SWAB VALVES. " ........ .-,r. 3 1/2" · TOP CON:,.. _ EUE UNION O:L. CO. Oi'-' '', ,,'., :A VCELL R F_CO R D ,. ~;-1L-~ ~'F A PAGE 1"!O._ [,;'.;ASE__KtlNAI BE__LUGA UNIT... _WELL NO..13_-8 ._ · FiE!,D_KE}~a[I GAg LOCz%TION, 805' S & 675' 12 of NE Corner of Sec. 18,.T4N, RI!W, S.M'. SPUD DATE 7/19/77 .. _COMP. DATE COi',.~Tt~ACTOip. __BRZ~KERHOF. F TYPE UNIT OILWELL 860 mc; NO..~ 59._ DRILL PiPE DESCRIPTION 5" E & S-135 PZXMIT NO. 77-29 SERIAL N0 ADL 22330 T.D. 8770' M9 T.V.D._7~564' VD DEVIATION (B.H.L.) 7101'S 8983' W. of Surface - .~: : ;~,~ HESS & LrESTER CO.vlPA~ ~ YEN G.:~ ,,ER -' ..' , o .x '~ TUBING 'GRADE DEPTH ELF;VATIONS: WA'I'EI[ DEI-q'H 1R.T. TO OCEAN FLOOR ~.T. TO MLL\V R.T. TO DR'ILL DECK 11.% TO PRODUCTION DECK APPROVED: THREAD SIZE .V/EIGHT P,'.R,_' O.{ATIHG RECORD 18.9' 8/25/77 II · !iLTE~LkL 7244-7264 7509 ' ret. PROD. TEST' _"BELUGA'' ZONE 9/5/77 9/8/77 9/9/77' 9/10/77 '-9/i4/77 - 9-7'1--~-/'7-7- 7040-7076 7004-7018 6852-6882 6820-6845 6790-6804 6466-6474 6446-6458 6820'6840 704'0-7076 5658-5694 5752-5770 5804-5830 5872-5912 6142-6148 6092-6098 5755-5765 ,~ 6005-6025 7501 ' Junk Il [ 6230' Ret° 6230' Ret. Il 11 SQZ'D W/100 sxs. w/.2.oo " SQZ'D 12/300 sxs "/ " OPEN FOR PRODUCTION. II II II II i,~RE-PERFED ). S_QZJ_IX__w_/_3n0- sxs,. (on 9/6/78,.) ~00 _sxs., . '" OPEN FOR PRODUCTION. I! II !1 II I1 " SQZ'D W/250 sxs. " SQZ'D 127250 sxs. " OPEN FOR PRODUCTION. }! I! l! Il II II II II II II II i]' II II i . TYPE: . INITIAL PIRODIJC'i'IO!'I · G~,~..v,[---C.I:'. T.P. ' C;,O+__tZ__~__3,_'i~I / / HE,xD:. CASING ' CASIR'G ' "' ' · HA:~G~R ...... CASING SPOOL: TUBING HEAD: TUBI~, G IIANGER:_ TUBING ilEAD TOP' ?.{ASTER VALVES: Ci-IF.,fSTM:\~; '['ilZE TOP C()NN.:. OIL OF CALIFOR 'IIA fLL IfCOI D VAGE i'Do I EASE IN~_LL ' ~.JO, KBU 13-8 FIELD .'ATE 7/18/77 7/19/77 7/20/77 ETD 20" cond. @ll4'RKB 169 'TD 20" cond. @ll4' 518'TD 20" cond. @114' DETAILS OF OPERATIONS, DESCRIPTIOI~S & RESULTS Staked surface location on 41-18 drill pad approximately 804'S & 675'W Of NE Corner of Section 18, T4N, RllW, S.M. 6/28/77 Moved const, equip, to K.G.F. 6/29/77 Started road construction and pad preparation for location site. 7./10/77 Completed site construction & road repairs, moved out const, equip. 7/11/77 Started turnkey rig move and rig up operations. 7/17/77 Completed turnkey rig move & rig up operations. Brinkerhoff ,Rig #59 went on company time - operating rate' @7:00 p.m. 7/17/77 7/18/77 Rigged up Delmag D-22 drive hammer & drove 20" - 94 drive conductor -to refusal @200 B.P.F. @ 114' below RKB or 95' below ground level.' Cut off 20" conductor 40" below ground level & installed O.C.T. 20" SOW X 20" 2M-MSP starting head. Installed 20" riser & 20" hydril - mixing spud mud. COST BREAKDOWN Location & site preparation Turnkey Rig Move & Rig up Co. Supervision- Opr. Rate Rig Charges 20" Conductor Contract Labor Mud Directional Charges Rental Radio Installation Fuel Transportation Drive Hammer TOTAL COST TO MIDNITE 7/18/77 = $261,155 $141,000 85 ,.000 8,800 10,227 4,000 2,000 1,198 5OO 85O 8OO 530 2,25O 4,000 (Footage 169') Completed installing 20" riser & hydril. Mixed spud mud. Picked up 17 1/2" bit & spudded well KBU 13-8 at 4:00 a.m.' 7/19/77. Cleaned out 20" conductor to 114'. Drlg 17 1/2" hole to 130'. Encountered sloughing gravel. Raised funnel viscosity to 200. Drlg 17 ,1/2" hole to 138'. Lost returns -mixed lost circulation material. Drlg to 147'. Total mud lost - 160 bbls. Pulled up to 20" shoe at 114'. Increased funnel vis. to 250 & mixed 200 bbls of mud w/ lost' circ. material. Drlg~17 1/2" hole from 147' to 169'. Mud loss minimal. (Footage 349'). Cont. drlg 17 1/2" hole from 169' to 195' in gravel and boulder bed. Maintained mud vis 250-300 SEC/QT & lost circ. material in mud. Drlg sand, silt & clay from 195' to 394'. Maintained mud as above, mud loss minimal. Survey 394' 1/4 deg N7W. Pooh for dyna drill Re-ran bit #1 '17' 1/2" on dyna drill BHA #2 & oriented at KOP of 394'. Dyna drill & survey from 394' to 518'. No major mud loss. Reduced mud vis to 100 SEC/QT. UNION OIL CCFP/V,h' CF CALIFO .IIA I LCOI D t'~AGE r.b, II -JNSE l'~LL l'~O, 13-8_ , FIELD ATE 3 7/21/77 4 7/22/77 5 7/23/77 6 7/24/77 7 7/25/77. _ . . 7/26/77 7/27/77 7/28/77 Il 7/29/77 ETD 937'TD 20" cond. @114 1852 TD 20" cond. @ll4 2508 TD 20" cond. @114 2508 TD 20" cond. @114 13 3/8" csg @2505' 2508'TD 2460'ETD (float colla 13 3/8" csg. @2505' 2508 'TD 2460 'ETD (float col lal 13 3/8" csg. @2505' 2977'TD 13 3/8" csg. @2505' 3457 'TD 13 3/8" csg. @2505' 3810'TD DETAILS OF OPERATIONS, DESCRIPTIOI'IS & RESULTS (Footage 419'). Cont. dyna drilling & surveying 17 1/2" hole from 518' to 695'. Pooh & ran angle bldg. BHA #3. Drilled & surveyed 17 1/2" hole from 695' to 937'. (Footage 915'). Drlg from 937' to 1852. (Footage 656'). Drlg from 1852' to 2508'. Circulated hole for casing and made short trip to 300'. Circulated for casing &'pooh with bit. Running 13 3/8" casing. (Footage 0') Ran and landed 13 3/8" 61# K-55 csg. @2505' w/ Dowell stab in float collar @2460'. Ran cementing tool on 5" DP and stung into float collar. Circulated hole clean with rig pump. Cemented w/ 1200 sx. Class "G" containing 2 1/2% prehydrated gel in mixing water mixed @98 lbs/cu.ft, followed by 200 sx. C1 '!G" neat mixed @ 116 lbs/cu.ft. Displaced cement to float collar and had good cement returns to surface. Pooh w/ DP. Cut off 13 3/8" csg. and installed OCT 20" 2000 X 13 3/8" 5000 psi. type TC csg. spool.. Nippled up BOPE. .(Foot. age 0')... Finished nippling up'12" 3000 psi BOPE, choke manifold and kill lines. Attempted to pressure test and valves ') failed in choke manifold and. r±g .pump ma~it~old. (Footage 0'). Finished repairing valves in choke manifold and pump manifold. Tested all BOPE, choke manifold, 'kill lines, pump ) manifold, Kelly, Kelly cocks, and surface mud lines to 3000 psi. Tested blind rams and 13 3/8" csg. to 2500 psi, Test completed at 9:00 p.m. Changed out blade sleeves on LOR stabilizers. (Footage 469'). Completed picking up BHA #6 & 12 1/4" bit #3. TIH - started taking weight on DP @1720'. Circ. btms up. Mud severely gelled & loaded w/ solids. Circ. & cond. mud - stage DP in hole - circ. out 3 times to top cmt. @2438'. Tested 13 3/8" casing to 2600 psi -o.k. Drill cmt., F.C. 02460' & cmt. to 2478'. Retested 13 3/8" casing to 2600 psi - o.k. Drilled cmt. & float shoe @2505'. C.O. rathole to 2508' & drilled to 2510'. Tested 13 3/8" casing seat and formation to .65 psi/ft, grad - held o.k. Directionally drilled.& surveyed 12 1/4" hole from 2510' to 2852' Pooh. Packed tandem BHA #7 to stop angle build. Re-ran 1~ 1/4" bit #3. Drilled & surveyed 12 1/4I' hole from 2852' to 2977'. (Foot~ge 480'). Drlg & surveyed from 2977' to 3009' w/ 12 1/4" bit #3 and tandem locked BHA #7. Angle increasing more than desired. Pooh to change BHA. Re-ran bit #3 on BHA #8 (under gauge near bit tandem assy). Drlg & survey to 3323'. Pooh. Ran 12 1/4" bit #4 on DD BHA #9, oriented dyna drill for maximum right hand turn w/ eye steering tool. Dyna drilled & surveyed From 3323' to 3457'. (Footage 353'). Ran 12 1/4"'bit #3 on dyna drill BHA //9 to TD UNION OIL CCFPANY OF CALIFOPCilA I ECORD ol PAGE III FIEI]') ATE 12 7/30/7 13 7/31/7 14 8/1/77 15 8/2/77 16 8/3/77 17 8/4/77 18 8/'5,,-' 77 19 8/6/77 20 8/7/77 ETD 13 3/8" csg. @ 2505' 4625' 13 3/8" @2505' 5629'TD 13 3/8" csg. 2505' 6353'TD 13 3/8" csg @2505 ' 7070'TD 13 3/8" csg. @2505' 7876 'TD 13 3/8" cs9 @2505' 8317.'..T~ ~ 13 3/8" csg, @2505' 8720 'TD 13 3/8" csg. @2505' 8770'TD 13 3/8" csg @2505' 8770'TD 13 3/8" csg. @2505' 9 5/8" csg. @8769' ETD 8726' (float. coll DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS @3457 - Oriented dyna drill w/ steering tool for maximum right hand turn. Dyna drilled to 3487'..Pooh. Re-ran Bit #3 and on BHA #10 - reamed dyna drill run and drilled 12 1/4" hole to 3502'. Plugged jet in bit. Pooh. Unplugged jet. Re-ran 12 1/4" bit #3 on BHA #11 and drilled to 3810'. (FoOtage 815'). Drilled & surveyed from 3810' to 3974'-4,,Pooh/ Ran 12 1/4" bit #4 on BHA #12 to drop angle. Drlg 12 1 hole to 4625'. (Footage 1004'). Dr'lg 12 1/4" hole w/ bit #4 and BHA #12 to 5186'. Pooh for' bit change. Drlg w/ bit #5 on BHA #12 5186' to 5629'. (Footage 724'). Drlg' & surveyed 12 1/4" hole from 5629' to 6084'. Had gas cut mud at surface. Circ. out gas cut mud - no flow. Drlg from 6084 to 6314'. Pooh for new bit. Had tight hole from 6314' to 4912' - 35-40M# excess drag. RIH w/ 12 1/4" bit #6 on BHA #12. Drlg from 6314' to 6353'. (Footage 717'). Drlg and surveyed 12 1/4" hole from 6353' to 6969'. Pooh to change bit and BHA. Tight hole pulling to 250M# from 6315' to 6504'. Ran 12 1/4" bit #7 on BHA #13 on 5" DP and drilled from 6969' to 7070'. (Footage 806"). Drlg and surveyed 12 1/4" hole from 7070' to 7876'. (Footage 441'). Drlg and surveyed 12 1/4" hole from 7876' to 7916'. Pooh for new bit. Ran 12 1/4" bit #8 on BHA #12 and drilled and surveyed 12 1/4" hole from 7916' to 8317'. (Footage 403'). Drlg and surveyed 12 1/4" hole from 8317' to to 8720'. Circ. and condition hole 'For logs and pooh. Schlumberger ran CNL-GR, BHC sonic, and DIL from 8711' (loggers TD) to 2505'. (Footage 50'). Ran RR bit #3 on BHA #12 and drilled 12 1/4" hole from 8720' to 8770'TD. Circ. and condition hole for 9 5/8" csg. and pooh. Changed rams in BOPE to .9 5/8". (Footage 0'). Ran and landed 216 jts 9 5/8" 47# N-80 butt csg. @8769' w/ float collar @8726'. Broke circulation w/ 500 psi in 1/4 hr and circulated bottoms up. Preceded cmt w/ 200 cu.ft. fresh water. Cemented w/ 3000 sx Cl "G" containing .75% D-31, .3% D-19, and .1% D-6 mixed @l l6~/cu, ft. Displaced cement to float collar w/ 640 bbl mud and bumped plug w/ 4000 psi. Released a~) pressure and floats held o.k. Cement channeled w/ returns to surface after 550 of 640 total bbl displacement pumped. CIP @6:00 p.m. 8/7/77. Hung 9 5/8" csg. w/ 150,000# and removed BOPE. Installed OCT 13 5/8" 5000 X 10" 5000 psi tbg. spool. OIL C(I BANY OF CALIFOF .IIA ' ELL I ECORD bt',EE, i PAGE IV LEASE ltELL NO. FIELD DATE 21 8/8/77 22 8/9/77 23. 8/~10/77 24 8/11/77 ETD 8770'TD 8726'ETD (float collar 13 3/8" csg. 02505' 9 5/8" csg. 08769' 8770'TD 8726'ETD (float collar 13 3/8" csg. 02505' 9 5/8" csg. @8769' 8770'TD 5630'ETD (cmt plug) 13 3/8" csg. 02505' 9 5/8" csg. @8769' 8770'TD 7518'ETD (cmt. plug) 13 3/8" csg. 02505' 9 5/8" csg. 08769' DETAILS OF OPEPATIONS, DESCRIPTIOHS & RESULTS Finished nippling up tbg. head and tested to 5000 psi. Nippled up 12" 3000 psi BOPE and tested to 3000 psi. Ran 8 1/2" bit #9 and and 9 5/8" csg. scraper on BHA #14 to top of cement @8642'. Unable to move 5" DP 0330,000#. RU circ. head and circulated out cement contaminated mud. Finished circ. out contaminated mud. Drilled out cmt. in 9 5/8" csg. from 8642' to 8715' F.C. (DP meas). Circ. & cond. mud for logs. Pooh. GO Int. ran GR-Neutron Aeoustic Signature cement bond log from 8711' (LTD) to 240.0'. Ran 9 5/8" Baker retrievamatic squeeze pkr on 5" DP and set 08200' to sqz. for.zone isolation above Tyonek Section. Test DP and pkr to 1500 psi. Finished testing 9 5/8" squeeze pkr @8200' and 5" DP. Perforated 4 HPF 8308' 5o 8310' for Tyonek zone isolation squeeze. Broke dwn. perfsw~200 psi and pumped in 011 cu ft/min & 3800 psi.. Squeezed perfs 8308-8310' w/ 150 sx. C1 "G" containing .75% D-31, .6% D-19 .1% D-6 to a final squeeze pressure of 4000 psi. Displaced cmt. to 8260'. Reversed hole clean and set pkr 07475'. Perfed 4 HPF 7568-7570' for Beluga zone isolation squeeze. Broke dwn. perfs @2200 psi and pumped in 0 13 1/2 cu.ft./min & 3000 psi. Squeezed perfs 7568'-7570' w/ 15Q sx. C1 "G" to a final squeeze pressure of 2900 psi. Reversed hole clean and set pkr @6194'. Perfed 4 HPF 6298'-6300' for Beluga zone isolation squeeze. Broke dwn. perfs @1200 psi and pumped in @24 cu.ft./min & 2000 psi. Squeezed perfs 6298'-6300' w/ 200 sx C1 "G" to a final squeeze pressure of 2600 psi. ~isplaced cmt. to 625?'. Reversed hole cle~n.and set pkr @55~6.. Per~ed. 4 ~PF 5658~-5660' for zone isolation sqz.. above meiuga. ~roKe-awn.'perTs @1100 psi & pumped in.@30 cu..ft./min.-&--1800 psi. Sqz. perfs 5658-5660' w/ 20Q. sx. C1 "G" containing 1% CaC12, 75% D-31, ,6% D-19,"..1% D-6 t~ a final sqz;pr~ssure of 1800 psi. Displaced cmt. to 5630'. Reversed hole clean and set pkr @5286'. Perf 4 HPF 5398' to 5400'-for ~terling zone isolation sqz. Finished perf 4 HPF 539~'-3400' £or'S~erltn$ Zone isolation ~q~. Broke dwn. perfs @1200 psi and pumped in @32 cu.ft./min & 1600 psi. Squeezed perfs 5398'.-5400'.w/ 200 sx. C1 "G" w/ .75% D-31 .6% D-19, .1% D-6, 1% CaC12 to a final pressure of 1400 psi. Reversed hole clean and set pkr 04970'. Perf 4 HPF 5058'-5060' for Sterling zone isolation squeeze. Broke dwn. perfs @1200 psi and pumped in @ 28 cu.ft./min & 1900 psi. Squeezed perfs 5058'-5060' w/ 150 sx. C1 "G" w/ additives as above to a final pressure of 1350 psi. Reversed hole clean and set pkr @4726'. Perf 4 HPF 4820'-4822' for zone isolation squeeze above Sterling. Broke dwn. perfs 0 1000 psi and pumped in @ 36 cu.ft./min & 1800 psi. Squeezed perfs 4820'-4822' w/ 200 sx. CI "G" w/ additives as above to a final pressure of 1300 psi. Reversed hole clean and pooh w/ pkr. Ran 8 t/2" RR bit #9 on BHA #15 and drilled out squeeze cmt. from 4734' to 7518'. ~ , IJNIOrl OIL CC iP/V Y OF CALIFO .IIA I LC0RD S EET PAGE LEASE I',F_LL N0, B-8 FIELD :2JATE 25 8/12/77 26 8/13/77 27 8/14/77 28 8/15/77 29 8/16/77 · ETD 8770'TD 5530' ETD RTBP 13 3/8'" ~sg. @2505' 9 5/8" csg. e~8769' 8770' TD 5480' ETD Sand on RTBP 13 .3/8" csg. @2505 9 5/8" csg. @8769' II II 8770'TD 5530' ETD . RTBP 13. 3/8" csg. @2505 9 5/8" ¢sg- @8769' 8770'TD 8718' ETD (fill on FC) 13 3/8" csg. i@2505' 9 5/8" csg. @8769' DETAILS OF OPERATIONS, DESCRIPTIO~IS g RESULTS ~= Finished drlg out squeezed cmt & clean out hole from 7518'- 8719' and circulate to cond. mud. Pooh w/ bit. Ran 9 5/8" Baker retrievamatic squeeze pkr on 5" DP and tested zone isolation squeezes: Squeeze No. Zone 1 Tyonke 8308'-8310' 2 Beluga Zone l 7568'-7570' 3 Beluga Zone 2 6298'-6300' 4 Top Beluga 5658'-5660' Test Grad. 1.03 .92 .85 .85 No. 5 squeeze in Sterling Zone #1 5398'-5400' leaked @.85 grad. and held,.72 grad. Pooh w/ pkr. Ran 9 5/8" Baker retrievable bridge plug and retrievamatic pkr on 5" DP. Set RTBP @5530' and tested to 2500 psi. Spotted 24 cu.ft, sand on top of RTBP and set pkr @5299'. Broke dwn. Sterling Zone #1 squeeze perfs 5398'-5400' @llO0 psi and pumped in @28 cu.ft./min. & 1800 psi. Resqueezed perfs 5398' to 5400' for isolation of Sterling Zone #1 with 300 sx. Class '~G" w/ 1% CaC12, .75% D-31, .6% D-19 and .1% D-6 to a final pressure of 1800 psi. Held pressure on squeeze 1 hr and reverse' out. WOC 3 hrs and attempt to test squeeze but pkr would not hold. Had full circulation both reverse and conventional'but could not move pkr. Backed off 5" DP @5134' and left in hole 5 jts 5" HWDP and retrievamatic pkr. Ran screw-in sub on jars & tied into top of fish @5134'. Circ. & jarred on fish - unable to work fish free. RU Dialog - ran free pt. Fish 25% free to top of packer @5290' B.O. DP @5165' & pooh. Ran R.S. on 5 jts of 8 1/8" O.D. wgshpipe. Tagged up on cmt. opposite #6 squeeze perfs @5058'-5060'. Reamed to top of fish @5165'. Washed over DP and C.O. to top of packer @5290'. Pooh w/ washpipe. Ran screw-in sub. Tied into top of fish @5165' & pooh. Recovered total fish. All fish recovered. Ran 9 5/8" Baker retrievamatic & set @ 4968'. Tested zone isolation squeeze #6 in Sterling Zone #2 5058'-5060' to .8 grad. Moved pkr to 4689' and tested zone isolation squeeze #7 in top Sterling Zone 4820'-4822' to .8 grad Pooh. Ran 8 1/2" bit #9RR on BHA #15 and drilled out squeeze cmt. 5329' to 5516'. Circulated hole clean and washed sand off RTBP @5535'. Pooh. Ran 9 5/8" Baker retrievamatic & set @5328'. Tested Zone isolation squeeze #5 in Sterling Zone #1 5398'-5400' to .8 grad. RIH and could not retrieve RTBP @5535'. Pooh and laid dwn. pkr. Ran Baker retrieving tool on 5" DP and cleaned out to top of RTBP @5535'. Finished cleaning out to RTBP @5535'. Retrieved RTBP and pooh. Ran 8 1/2" bit #9 RR on BHA #15 to ETD@8718' and circ. hole clean. Displaced entire mud system w/ fresh water and mix salt to raise weight to plus or minus 70#/cu.ft. UNIOtl OIL CCFP/V Y OF CALIFO .IIA CLL ICCORD SHEET D PAGE Ih, VI [..EASE I'ELL l,lO, B-8 FIELD D. ATE 30 8/17/77 31 8/18/77 32. 8/19/77 33 8/20/77 ETD 8770'TD 8250' ETD Perm. Pkr. 13 3/8" csg. @2505' 9 5/8" csg. @8769' pkl 8770'TD 8250 ' ETD Perm Pkr. 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 8250' ETD Perm Pkr. 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 8245'ETD(ret 13 3/8" csg. @2505' 9 5/8" csg. @8769' DETAILS OF OPEP2~TIONS, DESCRIPTIOI.IS & RESULTS Circ. w/ DP @8718' and conditioned WO fluid w/ addition of salt, CaC12, and Dril-S. Pooh w/ DP. Ran 8 1/2" gauge ring and junk basket on W.L. and could not work below 5300' (washed over Baker retrievamatic set @5298'). Ran 8 1/2" bit #9 RR and 9 5/8" csg. scraper on BHA #15 and worked scraper from 5244' to 5346'. RIH to 8718' and circ. btms. up. PoOh. Ran 8 1/2" gauge ring and junk basket on W.L. to 8300'. Ran 9 5/8" Baker Model "FA" pkr w/ 7"x9' mill@ut extension, 4 1/2" x 12' pup jt, and Otis 3 1/2" "XN" nipple tail. Set on W.L. @8250' w/ btm of ,~ tail @8277' Finished setting perm. pkr @8250' and RD W.L. tools. Ran 6"x4 1/2" x7' Baker seal assy on 5" DP and spaced out in pkr @8250'. Hooked up test manifold and separator and tested to 3000 psi. Tested 5"x9 5/8" annulus and pkr to 1000 psi. Pulled out of pkr and used 1200 psi gas pressure from #41-18 to blow DP dry to 2400'TVD. Stung into pkr @8250' and released gas pressure. GO Int. differentially perforated Tyonek w/ 4 HPF using 2 1/8" torpedo link-jet expendable gun 8334' to 8364' and 8660' to 8680' w/ no flow or pressure increase (hydrostatic pressure = 2850 psi). Pulled out of pkr and circulated hole w/ WO fluid. Pooh. Ran HOWCO 9 5/8" RTTS pkr and testing valve on dry 5" DP and set @8205'. Set 9 5/8" RTTS test pkr @8211' on dry 5" DP to DST Tyonek perfs 8334' to 8680'. Opened tool w/ surface valve shut in and pressure increased to 2100 psi in 6 1/2 hrs. Opened well thru test equipment and tested for 3 1/2 hrs @ rates of 96 to 162 MCFPD w/ 55 psi flowing surface pressure. Note: Rate increasing at time of final test & still unloading water. Released pkr and circulated hole w/ WO fluid. Pooh and layed do~ test tools. Well started flowing and shut in w/.150 psi. Stripped open ended 5" DP in hole thru hydril and circulated gas out @3900'. Mud severely gas cut and forming foam. Mud weight plus or minus 50#/cu.ft. Circ. rate 385 GPM. Shut in pumps. Well unloading at approx, same rate as pumping rate. Continued striping in hole w/ 5" DP open ended to 8235'. Annulus csg. press, llO0 psi. Required 190 psi to open DP back press, valve. Displaced well w/ 70#/cu.ft. 'clear chloride water and circ. out gas cut mud thru SWACO choke. Cleaned completion fluid allowing gas to break out at surface without any entrainment of gas and WO fluid .... pooh. Ran and set 9 5/8" cmt. retainer on W.L. @8245'. Ran 9 5/8" ) Baker retrievamatic test pkr and stimulation valve w/ 500' of water cushion on dry 5" DP and set @7510'. RU test equipment and tested to 3000 psi. Dry tested cmt. ret. - held o.k. GO Int. ran 2 1/8" perf §un to perforate Lower Beluga and could not get below stimulation valve. Released pkr and circ. hole w/ WO fluid. Pooh and removed stimulation valve. Ran 9 5/8" test pkr to 7510' and used 1400 psi gas pressure from #41-18 to blow 5" DP dry to 2800' TVD. Set Pkr ~ GO Int. d.if£erentially perforated Lower Beluga w/ 4 HPF using 2 1/8" tornado jet-link expendable gun 7578' to 7628'. UHIOi' OIL Cff ' Ph" Gf CALIFO qIA ' ELL S . EE-F PAGE VII I',F_LL HO, B-8 FIELD DATE 34 8/21/77 35 8/22/77 '36 8/23/7,7 37 8/24/77 38 8/25/77 ETD 3770' TD ~245' ETD (re t ) 3 3/8" csg. ~2505' 5/8" csg. 8769' 8770'TD 8245'ETD (ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 8245'ETD (ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 7509'ETD (ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770 'TD 7509'ETD 13 3/8" csg. @2505' 9 5/8" csg. @8769' DETAILS OF OPEPATIONS, DESCRIPTIOIIS g RESULTS Well unloaded and cleaned up bypassing surface test equipment for 10 hrs. Tested well for l0 hrs at .9 to 1.8 MMCFPD rate w/ 10 to 20 psi flowing surface pressure making minor amounts of water plus. or minus 4 BBLS/day. GO. Int. differentially perforated Lower Beluga w/ 4 HPF using 2 1/8" tornado jet-link expendable gun 8202' to 8218', 7892' to 7916' and 7840' to 7865'. ,! With 9 5/8" test tools set @7510' perforated the remaining lower 1/3 of the Beluga (test Beluga Interval #1) f/7776'-7812', 7672' to7680', 7642'-7662' using 2 1/8" OD GO Int tornado jet- link perf gun. Tested well & unloaded rathole fluid - attempting toi stabilize well. Making plus or minus 4.0 F~MCF/DAY - still unloading rathole fluid & mud. Prod. rate increasing as water unloaded. Stabilized lower Beluga test interval #1 (perfs 7578' to. 8218'), @4.25 MMCF/day. Shut-in well & ran Hewlitt-Packard pressure gauge & positioned @7875'. Re-stabilized rate @5.0 MMCF/day. Flow press, mid-perfs 439 psi, Stabilized well @ pipe line system conditions w/ 890 psi surface pressure (1047 psi BHP flowing). Well made 4.15 MMCF/day @ pipe line condi, tions. Shut-in well for BHP build up survey - 5 hrs. BHP = 2830 psi Pressure build up showed minimal formation damage, Killed well after testing lower Beluga test interval #1 from 7578' to 8218'. Pooh w/ Baker retrievamatic. RU GO Int. Ran 9 5/8" Model "K" cmt. ret. set at 7509'. RD GO Int. RIH w/ 9 5/8" Baker retrievamatic set at 6260'. Blew DP dwn. w/ 1300 psi of gas from #41-18. RU GO Int. Perforated Middle Beluga test interval #2 from 6344' .to 6384' w/ 2'1/8" tornado jet-link expendable gun. Well had good blow after shot Flow tested' Middle Beluga test interval #2. Fluid'level standing @1200' w/ perfs open from 6344'-6384'. Added perfs i'n Middle Beluga test interval #2 using 2 1/8" I.D. GO Int. tornado link perf gun as follows: 7244 -7264' 7040 -7076' 7004 -7018' 6852 -6882' 6820 -6845' 6790 -6804' 6466 -6474' 6446 -6458' Flow tested well. Fluid raised slowly to 350'. Killed well & pooh w/ DST tool. Re-ran DST w/ stimulation valve and DP dry. IJNION OIL G CALIFO 'IIA I ECORD S EET PAGE VIII LE SE t'ELL NO, rmu' zB-8 FIELD DATE ElD 39 8/26/77 40 8/27/77 41, 8/28/77 42 '8/29/77 43 8/30/77 8770'TD 7509'ETD (cmt ret) 13 3/8" csg @2505' 9 5/8" csg. @8769' 8770'TD 7509'ETD (cmt ret) 13 3/8" csg' @2505' 9 5/8" csg. @8769' 8770'TD 7509'ETD (cmt ret) 13 3/8" csg @2505' 9 5/8" csg. @8769' 8770'TD 6600'ETD (BP) 9 5/8" csg. @8769' 13 3/8" csg. @2505' 8770'TD 6600'ETD(BP) 9 5/8" csg. @8769' 13 3/8" csg. ~2505' ' DETAILS OF OPEPATIONS, DESCRIPTIOIIS & RESULTS Finished RIH w/ 9 5/8" Baker retrievamatic and stimulation valve on dry 5" DP and set pkr @6260'. Pressure DP w/ 1000 psi gas pressure from #41-18. Opened stimulation valve and bled off gas pressurer Flowed rathole mud to surface in 2 hrs and tested all Beluga interal #2 perfs'from 6344' to 7264' at 2.9 MMCFPD rate w/ 23 BWPH. Ran GO Int. W.L. spinner and temp survey while flowing well a~ 3.25 to 3.4 MMCFPD rate w/ 24 BWPH. Killed well w/ W.O. fluid and circulated hole clean. 'Lost 80 bbls fluid to formation. Pooh. Ran 9 5/8" Baker retrievamatic and stimulation valve on dry 5" DP and set pkr @6680'. Pressured DP w/ 1150 psi gas pressure from #41-18. Opened stimulation valve and bled off gas pressure. Flow tested lower Beluga interval #2 perfs from 6790' TO 7264'. (Upper Beluga interval #2 perfs 6344' TO 6474' isolated) at 4.7 MMCFPD rate w/ 2 BWPH for 10 hrs. Recovered drilling mud and water increased to t3 BWPH. Final test rate 4.9 MMCFPD rate w/ 13 BWPH (suspect water movement behind casing). 'Killed well w/ W.O. fluid and pooh. Ran Baker'9 5/8" bridge plug on GO Int. incomplete. Finished running 9 5/8" Baker Bridge plug on GO Int. W.L. and set @6600' to isolate Beluga interval #2 lower perfs 6790' to 7264' from Beluga interval #2 upper perfs 6344' to 6474'. Ran 9 5/8" retrievamatic pkr on 5" DP and set @6256'. Pumped in upper Beluga interval #2 perfs 63447 to 6474' @22 cfm & 1700. psi. Squeezed perfs 6344~ to 6474' w/ 250 sx.. C1 "G" w/ .75% D-31 and 1% CaC12 and staged cement 3 times in 1 hr after clearing pkr to a final pressure of 2500 psi. Released pkr and could not circ. Pooh and found soft cement in 20 jts of 5" DP. LD DP and washed out cmt. Ran 8 1/2" bit, 9 5/8" csg scraper and 6 DC on 5" DP and drilled out cement from 6261' to 6425' Washed to BP @6600' and circulated hole clean. Pooh. Ran 9'5/8" retrievamatic and stimulation valve on dry 5" DP, incomplete. Finished running 9 5/8" Baker retrievamatic pkr and stimulation valve on dry 5" DP and set pkr @6256'. Pressured DP to 1200 psi w/ gas from #41-18. Opened stimulation valve and bled pressure to O. Dry tested Beluga interval #2 upper perfs6344"' to 6474' after squeeze w/ no fluid entry in 3 hrs. Filled 'DP w/ W.O. fluid. Broke dwn. perfs6344' to 6474' w/ 2000 psi and pumped in @10 cfm &-1800 psi - held 650 psi w/ pump off. Re-squeezed Beluga interval #2 upper perfs6344.' to 6474' w/ 200 sx. C1 "G" w/ .75% D-31 and 1% CaC12 to a final pressure of 3200 psi. Bled to 2800 psi and held steady. Reversed hole clean and pooh. Ran 8 1/2" bit, 9 5/8" csg. scraper, and 6 DC on 5" DP and drilled out hard cmt. from 6368' to 6476'. Washed to ret. @6600' and circ. hole clean. Pooh. Ran 9 5/8" Baker retrievamatic pkr and stimulation valve on dry 5" DP and set pkr @6256'. Opened valve, surged and dry tested Beluga interval #2 upper perfs 6344' to 6474' w/ no entry in 1 1/2 hrs. Filled DP and circ. hole clean. Pooh. UIiIO!l OIL CCt'P/V ' OF CALIFOPCiIA t',[CORD. PAGE IX I', LL HO, :su ]_B-8 FIELD DATE 44 45 46 47 48 8131/77 9/i/77 9/2/77 9/3/77 9/4/77 ETD 8770'TD 7501" ETD (junk on cmt. ret) 9 5/8" csg. @8769' 13 3/8" csg. @2505' 8770'TD 7501 'ETD (junk on cmt. ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 7244 ' ETD (cmt.) 9 5/8" qsg. @87,69' 13' 3/8" csg. @2505' . 8770'TD 6790' ETD (cmt.) 9 5/8" csg. @8769' 13 3/8" csg. @2505' 8770'TD 7501 'ETD (junk on cmt re ) 9 5/8" csg. DETAILS OF OPEPATIONS, DESCRIPTIOIIS g RESULTS Finished pooh'w/ pkr. Ran 8 1/2" bit, 9 5/8" csg. scraper and 6 DC on 5" DP and drilled out cmt. ret. @6600'. Pushed and washed.ret, to 7360' w/ no cmt. across perfs 6790' to 7264'. Washed a~d reamed from 7360' to 7502' and circ. out large amount of fine formation sand. Circ. hole clean and pooh. Ran 9 5/8" retrievamatic and stimulation valve on dry 5" DP and set pkr :51' @6300'. Opened stimulation valve and tested Beluga interval. #2 lower perfs 6790'-to 7264' for 6 1/2 hrs @ max rate of 1'.25 MMCFPD and unloading rathole water. '~ Tested Beluga interval #2 perfs 6790' to 7264' for 23 hrs @min. rate of 1.5 MMCFPD plus 5.6 BWPH to max rate of 4.5 MMCFPD plus 3.2 BWPH. Total of 220BW recovered in 23 hrs for average water prod rate of 9.6 BWPH. Tested Beluga interval #2 lower perfs 6790' to 7264' for l0 hrs @ max rate of 4.9 MMCFPD plus 3.2 BWPH w/ 335 psi tbg. pressure. Average rate for 10 hrs'of 4.6 MMCFPD plus 8.6 BWPH. Killed well and RIH to sand fill @7050' (451' = 185 cu.ft.) Washed out sand to 7275' and circulated to condition W.O. fluid. Set pkr @7144'.' Broke dwn. perfs 7244'-7264' @2400 psi and pumped .in @19 CFM & 2500 psi. Squeezed perfs 7244'-7264' w/ 100 sx Class "G" containing .75% D-31 and 1% CaC12 to a final pressure of 2900 psi. Reversed out and pulled up to 6700'. Circ. & condition mud while WOC 3 hrs. Set pkr @6926'. Broke dwn. perfs 7004'-7018' and 7040'-7076' 1800 psi and pumped in @ 18 CFM & 21oo psi. Squeezed perfs 7004'-7076' w/ 200 sx. C1 "G" containing .75% D-31 and 1% CaC12 to a final pressure of 2600 psi and bled off to 1500 psi in 1/2 hr~ Reversed out and pulled up to 6676'. Circ. and cond. mud while WOC 3 hrs. Set pkr @6676'. Broke dwn. perfs 6790'-6804', 6820'-6845' and 6852'-6882' w/ 1500 psi and pumped in @19.5 cfm & 1900 psi. Squeezed perfs 6790'-6882' w/ 300 sx. CI "G" containing .75% D-31 and 1% CaC12 to a final pressure of 3000 psi and bled off to 1500 psi in 1/2 hr. Revesred out and pulled up to 6250'. Circ. and condition mUd while WOC 3 hrs. Pressure test squeezed perfs 6344'-6474' to .85 grad. and bled to .74 grad. and held. Moved pkr to 6676' and pressure perfs 6790'-6882' to .85 grad. Bled off to .74 grad. and held. Pooh. Ran 8 1/2" bit, 9 5/8" csg. scraper and 6 DC on 5" DP. CO squeze cmt 6678'-6930', 6950'-7080', 7238'-7313'. Washed out sand to 7501'ETD and circ. hole clean. Pooh. Ran GO Int. CBL signature log from 7465' to 4000'. LD 5" ' HWDP. Ran 9 5/8" HOWCO RTTS pkr and APR valve on 2 7/8" 6.4# N-80 butt. tbg., incomplete. Ur'tIO['l OIL CCF£/V,, G CALIFO 'IIA I',ELL t?,ECORD StiEET PAGE LEASE I', LL HO,=B'8 FIELD ,2ATE 49 51 52 ETD 9/5/7Z' 9/6/77 9/7/77 9/8/77 8770'TD 7501 'ETD 13 3/8" csg @2505' 9 5/8" csg, @8769' 8770'TD 7501 'ETD (junk on cmt ret) 13 3/8" csg, @2505' 9 5/8" csg. @8769' 8770'TD 6230' ETD (ret) 13 3/8" csg, csg @2505' 9 5/8" csg. @8769' 8770'TD 6230'ETD (cmt ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESUI_TS .$e.~. pkr.@6250' and p~essur6d'annulus toi~Z~U psi to open APR valve, Dry tested:squeezed perfs~6344' to 726~' for 3/4'hrs, w/ only slight, blow in bubble'bucket, Moved pkr to 6750' and dry tested squeezed perfs 6790' to 7264' for 1 hr w/ only slight blow in bubble bucket and pressure loss from 1200 psi to 900 psi on annulus, Located tbg, leak and retested perfs 6790' to 7264' for 1/2 hr w/ only slight blow in bubble bucket, Reperf Beluga interval #2 lower perfs w/ 4 HPF using 2 1/8" torpedo jet-link expendable gun 6820' to 6840'," Checked F,L, @5350' in tbg, after perf (1400' = 45 cu,ft, entry), Gas. rate too small to measure thru separator, ~eperf Beluga interval #2 lower pers as above 7040' to 7076', Gas rate still too small to measure, Pooh w/ tbg, to reperf w/ 4" csg, gun, Killed well and pooh, GO Int, reperf w/ 4 HPF using 4" DML 25 gm charge 7040' to 7076' and 6820' to 6840', Ran 9 5/8" HOWCO test pkr and APR valve on dry 2 7/8" tbg, and set pkr @6750', .Opened APR valve @11'00 a,m, Flow tested well thru by pass for 2 hrs w/ gas rate too small to measure. Shut in 1 hr. and pressure built up to 270 psi, Flow tested well thru by pass 4 hrs, @ very low gas rate, Flow tested well thru sep, for 6 hrs. Time Rate Water TP 7:00 240 MCFPD 12,8 BWPH 3-'~psi 9:00 340 2,8 35 11'00 450 2.5 45 12-00 475 1.5 55 Tested Beluga interval #2 reperfs 7040' to 7076' and 6820' to 6840' for 10 hrs at max rate of 1,9 MMCFPD plus ,8 BWPH, Killed well and RIH to fill @7402' (suspect sand = 41 cu,ft,),- Could not clean out fill w/ test pkr, Circ. btms. up and pooh. GO Int. set 9 5/8" cmt, ret, @6230', Removed 12" 3000 psi BOPE to replace w/ 10" 5000 psi BOPE, Finished removing 12" 3000 psi BOPE and NU 10" 5000 psi double gate Shaffer and 10" 5000 psi hydril, Tested BOPE to 3000 psi, Ran 9 5/8" HOWCO test pkr and APR valve on dry 2 7/8" tbg,. and set pkr @5592', Opened APR valve w/ 1100 psi on annulus. GO Int~ perfed Beluga Test Interval #3 w/ 4 HPF using 2 1/8" torpedo jet link expendable gun 5658"to~5694'o Tested well for 4 hrs. @ max rate of 7.4 MMCFPD plus ,3 BWPH water. LEASE UHIO!I OIL G CALIFO 'IIA ',ELL I ECO,RD 13-8 FIELD S, EET PAGE xI DATE 53 9/9/77 54 9/.10/77 55 .9/11/77 9/12/77 57 9/13/77 ETD 8770'TD 6230' ETD 13 3/8" csg@2505' 9 5/8"csg @8769' 8770'TD 6230'ETD 13 3/8" csg@2505' 9 5/8" cs @8769' 8770'TD 6230'ETD 13 3/8" csg@2505' 9 5/8"csg csg@8769' 8770'TD 5845'ETD (cmt ret) 13 3/8" csg@2505' 9 5/8" csg@8769' 8770'TD 6220' ETD (junk on cmt ret) 1 3 3/8" csg@2505' DETAILS OF OPEP2~TIONS, DESCRIPTIOIIS & RESULTS With 9 5/8" cmt, ret @6230' and 9 5/8" test p'kr set @5592' on 2 7/8" tbg, GO Int, cont. perf, Beluga test interval #3 w/ 4 HPF using 2 1/8" torpedo jet link expendable gun @5752" to 5770', Tested entire Beluga interval #3 perfs 5658' to 5770'.for 5 1/2 hrs, @ max rate of 8,5 MMCFPD plus 0 BWPH w/ 455 psi TP, Ran perf gun to perf, next interval and gun hung up in 2 7/8" tbg, @1850', Pulled gun in two, Killed well and pooh w/ tbg, Ran 9 5/8" Baker retrievamatic pkr & stimulation valve on dry 5" DP and set pkr @5600', Opened valve and flow welZ to clean VP for 2 3/4 hrs, @ rate of 9.8 MMCFPD plus 0 BWPH w/ 940 psi TP, Ran perf gun to perforate next interval and could not get thru stimulation valve, Killed well and pooh w/ DP, Ran 9 5/8" HOWCO RTTS and APR valve on 5" DP and set @5593', Openen valve and flow well to clean up for 2 1/2 hrs @ max rate of 7.3 MMCFPD plus 1 BWPH w/ 380 psi TP, GO Int, cont, perf, Beluga test interval #3 as above @5804' to 5830', Tested entire Beluga interval #3 perfs 5658' to 5830' for 5 1/2 hrs. @ max, rate of 13,3 MMCFPD plus 3,2 BWPH w/ 880 psi TP, GO I'nt. cont, perf, Beluga test interval #3 as above @5872' to 5912', Tested entire Beluga interval #3 perfs 5658' to 5912' for 14 hrs @ max rate of 15,75 MMCFPD plus 5 1/2 BWPH w/ 900 psi TP. ..' Recoverd 72 BW in 12 hrs (4 1/2 BW rathole volume) for avg. of 6 BWPH, Killed well and pooh w/ DP. Ran 9 5/8" HOWCO cmt ret on WL and stuck ret @5872' in perfs, 5872' to 5912', Ran stinger on 5" DP and tested ret @5872' w/ good circ, Pooh, Ran 8 1/2" RR bit #10 and 9 5/8" csg..scraper on 5" DP and drilled out ret, Pushed ret to 6230'ETD. and circ, hole clean, Finished circ, hole clean @6230'ETD and pooh. Ran 9 5/8" Howco. cmt. ret, on W,L, and set @5845'. Ran stinger on 5" DP and pumped in Beluga teSt interval #3 perfs 5872'-5912' @17CFM & 1950 psi, Held 650 psi w/ pump off.' Squeezed perfs 5872'-5912' w/ 250 sx, Class "G" cmt w/ .75% D-31 and 1% CaC12 to a final pressure of 3000 psi, Press. bled to 2600 psi and held, Pulled out of ret, and pooh, Ran 9 5/8" Howco cmt ret, on W,L. and set @5774'. Ran stinger on 5" DP and pumped in Beluga test interval #3 perfs 5804' to 5830' @17 1/2 CFM & 2300 psi. Held 700 psi w/ pump off, Sqz, perfs 5804' to 5830' w/ 250 sx, C1 "G" cmt w/ ,75% D-31 and 1% CaC12 to a final pressure of 2500 psi. Press, bled to 2000 psi and held. Pulled out of ret, and pooh. Ran 8 1/2" RR bit #10 and 9 5/8" csg, scraper on 5" DP-to 5600' and WOC total of 5 hrs, Drilled cmt ret @5774' and hard cmt. to 5830'. Washed to ret @5845' and now drlg on cmt ret. Drlg on ret @5845' 2 hrs w/ RR bit #10 and pooh for new bit. Ran bit #11 and 9 5/8" csg, scraper on 5" DP and drlg ret @5845' and hard cmt to 5878' in 7 1/2 hrs. Pooh and ran bit #12 and 9 5/8" csg. scraper on 5" DP, Drlg hard cmt to 5920' and washed to junk on cmt ret @6220'. Circ. hole clean and cond, mud, Pooh, OIL CCI'. /V CF G LIFC.'? IIA I,ELL l'r rn, n ~'i~_LL IlO, KBU. 13-8 FIELD 58 9/14/77 59 9/15/77 60 9/16/77 61 9/17/77 62 9/18/77 ET~ 8770'TD 6220' ETD (junk on cmt ret) 13 3/8" csg@2505 9 5/8" csg@8769 8770' TD 6220' ETD (junk on cmt ret) 13 3/8" csg@2505 9 5/8" csg@8769 87'70'TD 8245'ETD (cmt ret) 13 3/8" csg@2505' 9 5/8" csg@8769' 8770'TD 8245'ETD (cmt ret) 13 3/8" csg@2505' 9 5/8" csg@8769' 8770'TD 6975'ETD (cmt ret) 13 3/8" csg@2505' 9 5/8" csg@8769' DETAILS OF CPEP2~TIONS, DESCRIPTIOI1S & RESUI_TS RIH . Set Howco pkr @5780' for dry test. Formation taking fluid thru perfs @5752' to 577~' & 5658' to 5694'. Could not dry test~ Pulled back to 5598 . Set HowCo pkr, opened Howco APR valve.' Put well on test. Started testing upper Beluga perfs 5658' to 5694' and 5752' to 5770'. Well cleaned up 11MMCF/day - no water cut. Shut in well - fianl rate 12.125 MMCF/day - no water cut. Perf upper Beluga 6142'-6148'DIL w/ 4 HPF using GO Int. 2 1/8" torpedo jet-link expendable gun under drawdown conditions. Put well back on test at 3:00 p.m., Rate at 6:00 p.m. 13.5 MMCF/day - no water cut. Water cut started back up & rate decreasing. Rate at 12:00 p.m. plus or minus '12.0 MMCF/day - 4 BWPH. Prod. tested Upper Beluga test Int. #3. Perfs open 5658' 5694', 5752' to 5770' (perfs not showing on log) and 6142' to 6148' Prod. test at 13.$MMCF/day - 29 BWPD. Added perfs 60~2' to 6098'. Tested at 15.5 MMCF/day - 14.4 BWPD. Reperf 5755' to 5765'.. Rate 'increased 18.1MMCF/day - 14.4 BWPD. Added perfs f/6005' to 6025'. Flow tested for 7 hrs BelUga test interval #3 perfs' 5658'-5694', 5752' to 5770', 6005' to 6025', 6092' to 6098' and 6142' to 6148' @ final rate of 17.5 MMCFPD plus 0 BW w/ 1120 psi DP press. Shut.well in for 1 hr and pressure built to 1560 psi. Killed well and circ. to condition W.O. fluid. Pooh. Ran 8 1/2" bit #13 on BHA #15 and drilled out cmt ret.@6230 and 7509'. CO 9 5/8" csg. to cmt ret @8245'ETD and circ. to cond. W.O. fluid. Pooh. Ran Howco 9 5/8" RTBP and RTTS test pkr on'5'~ DP and set RTPB @7113' w/ pkr @ 7020' to straddle Beluga test interval ~2 perfs 7040' to 7076' PI perfs for hydroxy. aluminum, sand control sqQeez6..~@ i-1/2.CFM & 1850 psil. Started sand control squeeze pumping 1470 gal 15% Hcl, 2940 gal 5% KC1, and 847 gal hydroxy aluminum. With 276 gal 15% HC1 into formation had upward communication to squeezed perfs 7004' to 7018'. Rev. out and moved RTTS pkr to 6980' to straddle squeezed perfs 7004' to 7018' and open perfs 7040' to 7076'. Cont. sand control squeeze and had upward communication to perfs group between 6790' to 6882' (squeezed & reperf @6820' to 6840') w/ 1386 gal 15% HC1 in formation. Ran in to RTBP @ 7113' and circ. btms up. Retrieved RTBP and pooh. Set 9'5/8" Baker cmt ret on W.L. @7325' and 6975'. Ran stinger on 5" DP to ret @6975'. PI Beluga test interval #2 perfs 7040' to.7076' (and squeezed perfs 7004' to 7018'.) @ 15 CFM & 2000 psi and had upward communication to perfs group 6790' to 6882'. Pumped and rotated out of cmt ret @6975' w/ ~5,000# above string wt. Circ. hole clean and rec. fine formation sand. Pooh. Ran 9 5/8" RTTS pkr on 5" DP and set @6754'. PI perfs 6820' to 6840' (6790' to 6804' and 6852' to 6882' squeezed & not reper~@ 1-6 CFM & 1900 psi. Held 800 psi w/ pump off. Squeezed Beluga test interval #2 perfs 6820' to 6840' (and squeezed perfs as above) w/ 300 sx. C1 "G" cmt w/ .75% CFR-2 & 1% CaC12 to final pressure of 3200 psi @11/2 CFM. Bled to 2400 psi & held. Released pkr and pooh. Ran 8 1/2" bit #14 on BHA #15 on 5" DP and WOC 5 hrs. Drlg cmt. from 6537' (217' = 89 cu.ft, bleed back) to 6641' OIL CF CALIFO?CIIA I,ELL i ~';~LL IlO. KBU 13-8 FI,_LD 2ATE 63 9./19/77 64 9/2O/77 65 9/21/77 66 9/22/77 67 9/23/77 68 9/24/77 69 9/25/77 ETD 8770'TD 7071' ETD cmt. 13 3/8" cs§. @2505'. 9 5/8" csg. @ 8769' 8770'TD 8245'ETD(ret 13 3/8" csg @2505' 9 5/8" csg. '@8769' 8770'TD 7450' ETD Perm Pkr. 13 3/8" csg. 9 5/8" csg. @2505' 8770'TD 7450' ETD Perm Pkr. 13 3/8" csg. 9 5/8" csg~ @2505' 8770'TD 7450' ETD Perm Pkr. 13 3/8" csg. 9 5/8" csg. @2505' 8770'TD 7450" ETD Perm 'Pkr. 13 3/8" csg. 9 5/8" csg. @2505' 8770'TD 7450' ETD Perm Pkr. 13 3/8" csg. 9 5/8'" csg. @2505' DETAILS OF OPEPS'~TiONS, DESCRIPTIOIIS g RESULTS Drlg cmt 6641' to 6880' (base of sqz perfs). No cmt from 6880' to top of ret at 6975'. 'Drlg cmt ret at 6975'. No cmt to ret at 7325'. Pooh. Ran sqz. tool & set at 6975'. Broke dwn. perfs 700~"to 7018' and 7040' to 7076' at 2250 psi - '.C :. 15 cu.ft./mi~n. Formation held 1200 psi w/o pump. Sqz. perfs ..'/ w/ 200 sx C1 "G" w/ additives to a final press of 2800 psi. CIP at 12:20 p.m. Pooh w/ sqz. tool. Ran 8 1/2" bit & scraper. Tagged cmt. 6881' Drlg cmt. from 68.81' to 7071' (base of perfs). Bit tgrqued. Pooh. Lost 2 bolts off of Baker csg. scraper. LD scraper. Completed TIH w/ 8 1/2" bit. Tagged cmt. @7071'. Drlg firm cmt to 7150'. CO (no cmt) to ret @7325'. Drlg ret & CO to ETD @8245'. Pooh w/ bit & ran 2 7/8" tbg in hole & pooh laying dwn same. RU GO Int. Ran W.L. gage ring - unable to get below 6200'. Could not work 8.5" od gage ring below 6200' w/ W.L. Pooh and RD W.L. tools. Ran 8 1/2" bit #14 and 9 5/8" csg. scraper on 5" DP to 8245' ETD and circ btms up. Pooh. Ran 8.5" od gage ring on W..L. and could not work below 6343'. Ran 8.25" od gage ring on W.L. to 7500'. Set Baker 9 5/8" x 4 3/4" Model D pkr on W.L. @7450'. Ran Baker seal assy on 5" DP and tested pkr @7450' to 1000 psi. Pooh and LD 5', DP. Finished pooh and LD 5" DP and seal assy. RU casing crew and began running 2 7/8" 6.4# N-80 Armco seal-lok long string tbg. Ran dual 2 7/8" long string and 3 1/2" 9.2# N-80 butt short string tbg. to plus or minus 3550'. Circ. from 3550' and raise mud wt to 72# to pooh. Pulled dual tbg. strings. Changed out defective OCT 13 5/8" 5000 x 10" 5000 psi tbg. spool for CIW 12" 3000 x 10" 5000 psi DCB tbg spodl. Clean and sort. scaled and rusted 2 7/8" tbg. Finished cleaning and sorting 2 7/8" tbg. Ran 2 7/8" Armco seal lock 6.4# N-80 long string and 3 1/2" 9.2# N-80 butt short string tbg. Spaced out & landed long string in Baker Model D pkr @7450' w/ Baker single hydraulic pkr @ 6241'.. Spaced out & landed short string w/ Baker dual hydraulic pkr @ 5564~. Rigged Otis W.L. unit and checked "XA" sleeves in lon'g string. Ran "X" plug and stuck in "XA" sleeve @7431' Jarred on plug w/o success. Cut W.L. and ran fishing 'too~ls w/ new' jars. Jarred on plug w/o success.' Cut W.L. and RU braided W.L. unit. Made 3 runs w/ fishing tools and recovered all W.L. tools. Left "X" plug in "XA" sleeve @ 7431' Set Baker single hydraulic pkr @ 6241'- Ran "XN" plug' in short string and set in "XN" nipple @5594' Set Baker dual hydraulic pkr ~5564'. Retrieved "XN" plug from shQrt string. OIL COF? C, F CF O]LIFC?J]IA ' "' , '[' FPO41 ,LLL xIV ~,i'ELL ~i0, KBU 13-8 FIELD 2.ATE 70 9-/26/77 71 9/27/77 72 9/28/77 9/29/77 ETD 8770'TD /450 ' ETD Perm Pkr. 13 3/8': csg. 22505 ' 9 5/8" csg. 28769' 8770' TD 7450' ETD 'erm Pkr. .3 3/8" csg. ~q2505' ' 5/8" csg. ~8769' 8770' ID 7450' ETD 'erm Pkr. .3 3/8" csg. 32505' 9 5/8" csg. ~q8769' 5770' TD 7450 ' ETD Perm Pkr. 13 3/8" csg. 22505' 9 5/8" csg. 38769' DETAILS OF CPE?Y, Ti~r,o, DESCRIPTIC~iS g RESULTS Ran W.L. tools and attempted to retrieve "X" plug @ 7431'in Long Str~ng. .Retrieving'tool not holding i_atch. Ran 1 1/2" -.1 7/8" bailer and cleaned out sca~e on top of plug. Re-ran retrieying tool w/o success. Ran 2 1/4" bailer and 1 7/8" bailer to clean out scale on plug. Re-ran retrieving tool w/ no success. Ran W.L. bailer and cleaned out scale on top of X plug @ 7431' in .2 7/8" long string. Ran spear and hydraulic jars on W.L. and engaged plug. Jarred plug out of XA sleeve and sheared off W.L. tools. Pumped down long string and pumped X plug out end of tbg. Installed CIW back pressure valves in tbg. and ND BOPE. Finished ND BOPE. Installed CIW dual 3 1/2" 5000 psi X mas tree and pulled BPV. Rigged Otis W.L. unit and opened ~XA" sleeves @ 559~' in long string and 5484' in short string (dual hy pkr @5564,). Connected gas from #41-18 to tbg. strings and blow down to plus or minus 3200'. Closed sleeve in short string and flowed well to clean up thru short string while injecting gas thru long string. Closed sleeve in long string. Now flowing both short and long strings to clean up. Released rig @12:00 mid 9/28/77. Rigging down and moving out Brinkerhoff Drilling Co. Rig #59. Continued production testing long string tbg. on Lower Beluga zone perfs - rate increasing. Present rate 2.65 MMCF/day - no water - 130 psi tbg. press. Tested short string, tbg. on Upper Beluga zone perfs. Present rate 10.5 MMCF/day - no water - 1200 psi tbg. press. Kenai Beluga Unit Kenai Gas Field JTS. KENAI BELUGA UNIT 13-8 20" 1/2" Wall Plain End Drive Pipe DESCRIPTION LENGTH TOP BOTTOM. 20" 1/2" Wall Csg. 20" 1/2" Wall Csg. 20" 1/2" Wall Csg. 20".S.O.W. 20" Type 22 Csg. Hd. w/ 2-2" Threaded Outlet. KB to 20" Flange 38.50 75.50 ll4.00 40.00 35.50 75.50 14.00 21.50 35.50 1.50 20.00 21.50 20.00 ,..00 20.00 Used 1.5' 20" to make Drive Shoe welded on inside I.D. 18". Drove 95' Below Ground Level - Cut off 40" below Ground Level. C~g. Hd. 2' Below Ground Level. Kenai Beluga Unit Kenai Gas Field JTS. 1 213 JTS. *59 KENAI BELUGA UNIT 13-8 CASING DETAILS ! .. 9 5/8" CSG DEscRIPTION LENGTH BOTTO~L.. TOP 9 5/8'.' Baker Float Shoe 9 5/8"'47# N-80 Butt Csg. 9 5/8" Baker Float Collar 9 5/8" 47# N-80 Butt Csg. 9 5/8" 47# N-80 Pup Jt. KB to 12" 3M# Csg. Hd. Spool 1.82 8767.18 8769.00 39.55 8727.63 8767.18 1.68 8725.95 8727.63 8674.29 51.66 8725.95 32.76 18.90 51.66 18.90 .00 18.90 Total Csg. in Hole 8,746.60' (Includes Cut Off) Total Jts. 214 + 1 Cut Off (3276') Actual 9 5/8" Bottom 8750.10' From Ground Level. 13 3/8" CSG DESCRIPTION LENGTH BOTTOM 13 3/8" Dowell F1 oat Shoe 13 3/8" 61# K-55 Butt Csg. 13 3/8" Dowell Stab-In F1 oat Collar 13 3/8" 61# K-55 Butt Csg. KB Elevation * Includes one 18' Pup Jt.' TOP 1.80 2503.60 2505.40 41.48 2462.12 2503.60 2.05 2460.07 2462.12 2439.56 20.51 2460.07 20.51 .00 20.51 '.~:,~ Kenai Beluga Unit ',[I I ii~ 13-8 c::I~ ~ . ~. ;........ ~ I '. ~. _ ~..., / Kenai Gas Field JOINTS 1 1 3 5 6 8 17 9 11 4 6 8 4 8 1 15 19 19 9 14 3 DESCRIPTION KENAI BELUGA UNIT 13-8 1/2" TUBING DETAIL LENGTH Otis 3½" XN Nipple 3½" 9.2# N-80 Butt 9 5/81' 3 1/2" x 2 7/8" Baker AS 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Otis 3½" XA Sleeve 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½' 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-BO Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt, Otis 3½" XA Sleeve 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt' 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt 3½" 9.2# N-80 Butt Pup 3½" 9.2# N-80 Butt Cameron Split Hanger KB BOTTOM TOP 1.20 5594.63 5593.43 29.41 5593.-43 5564.02 10.75 5564.02 5553.27 8.13 5553.27 5545.14 60.76 5545.14 5484.38 4.10 5484,38 5480.20 31.50 5480.20 5448.78 6.20 5448.78 5442.58 91.59 5442.58 5350.99 6.08 5350.99 5344.91 152.06 5344.91 5192.85 5.17 5192.85 5187.68 178.75 5187.68 5008.93 4.10 5008.93 5004.83 242.79 5004.83 4762.04 4:lD 4762.04 4757.94 545.32 4757.94 4212.62 5.10 4212.62 4207.52 273.63 4207.52 3933.89 5. O0 3933.89 3928.89 335.52 3928.89 3593.37 4.20 3593.37 3589.17 151.80 3589.17 3437.37 4.10 3437.37 3433.27 121.54 3433.27 3311.73 4.'05 3311.73 3307.68 183.21 3307.68 3124.47 4.10 3124.47 31 20.37 241.51 3120.37 2878.86 3.10 2878.86 2875.76 121.60 2875.76 2754.16 10.30 2754.16 2743.86 241.55 2743.86 2502.31 10.30 2502.31 2492.01 30.78 -2492.01 2461.23 4.10 2461.23 2457.13 450.42 2457.13 2006.71 10.20 2006.71 1996.51 579.15 1996.51 1417.36 10.05 1417.36 1407.31 577.17 1407.31 830.14 10.40 830.14 ~8t9', 275.07 819.74 544.67 10.20 544.67 534.47 428.65 534.47 105.82 6.10 105.82 99.72 86.55 99.72~ 13.17 1.00 13.17 12.17 12.17 12.17 .00 '~,:cF Kenai Beluga Unit ....... Kenai Gas Field JOINTS 1 1 1 37 1 1 1 1 6 1 96 79 KENAI BELUGA UNIT 13-8 2 7/8" TUBING DETAIL DESCRIPTION LENGTH BOTTOM 2 7/8" Otis Mule Shoe 2 7/8" 6.4# N-80 Seal Lock 2 7/8" Otis x Nipple 2 7/8" 6.4# N-80 Seal Lock Baker Seal Assy & Locator 2 7/8" 6.4# N-80 Seal Lock Otis XA Sleeve 2 7/8" 6.4# N-80 Seal Lock Otis XA Sleeve 2 7/8" 6.4# N-80 Seal Lock Baker FH Packer 2 7/8" 6.4# N-80 Seal Lock Otis XA Sleeve 2 7/8" 6.4# N-80 Seal Lock 2 7/8" Baker Blast Joints 2 7/8" 6.4# N-80 Seal Lock 2 7/8" Baker Blast Joints 2 7/8" 6.4# N-80 Seal Lock 2 7/8" 6.4# N-80 Seal Lock Pup 2 7/8" Baker Blast Joints 2 7/8" 6.4# N-80 Seal Lock 2 7/8" Baker Blast Joints 2 7/8" 6.4# N-80 Seal Lock Otis XA Sleeve 2 7/8" 6.4# N-80 Seal Lock 9 5/8" x 3½" x 2 7/8" Baker 2 7/8" 6.40# N-80 Seal Lock Pup 2 7/8" 6.40# N-80 Seal Lock Otis XA Sleeve 2 7/8" 6.40# N-80 Seal Lock Otis XA Sl-eeve 2 7/8" 6.40# N-80 Seal Loc~ XO 2 7/8" Seal Lock x 3½ Butt 3~" 9.2# Butt Tubing Cameron Split Hanger KB TOP .68 7545.91 7545.23 30.97 7545.23 7514.26 1.10 7514.26 7513.16 31.75 7513.16 7481.41 18.37 7481.41 7463.04 31.65 7463.04 7431.39 3.60 743~.39 7427.79 1,143.65 7427.79 6284.14 3.60 6284.14 6280.54 30.25 6280.54 6250.29 9.24 6250.29 6241.05 30.38 6241.05 6210.67 3.60 6210.67 6207.07 31.09 6207.07 6175.98 100.00 6175.98 6075.98 30.30 6075.98 6045.68 60. O0 6045.68 5985.68 185.06 5985.68 5800.62 8. O0 5800.62 5792.62 40. O0 5792.62 5752.62 30.21 5752.62 5722.41 60.00 5722.41 5662.41 63.19 5662.41 5599.22 3.60 5599.22 5595.62 31.60 5595.62 5564.02 13.16 5564.02 5550.86 4.10 5550.86 5546.76 30.40 5546.76 5516.36 3.60 5516.36 5512.76 2979.57 551 2.76 2533.19 3.60 2533.19 2529.59 2455.07 2529.59 74.52 1.80 74.52 72.72 59.02 72.72 13.70 1.00 13.70 12.70 12.70 12.70 .00 KB - CSG Head 18.90' Well Schematic KGF 13-8 Kenai Gas Field 20"½ Wall Plain End Drive Pipe Set @ ll4' Baker Dual PKR 9 5/8 x 3½ x 2 7/8 @ 5550.86' 13 3/8 61# K-55 Butt CSG Set @ 2505.40 Baker ~ 5/8 x 2 7/8 mod. "FH" PKR Fa 6241.r)5 · _Baker 9 5/8 x 2 7/8 PKR Fa 7463.04' , Started 7-17-77 Compl et_ed__l 0-2-77 · __ UI'ilCN OiL COMPANY OF CALIPO2NIA 9 5/8 47# N-80 Butt CSG Set @ 8769. . D ~.AWN ' _ i i iii i iii ii BIT RECORD COUNTY ISECTION ITOWNSHIP IRANGE LENAL 0 C A T I 0 N lWELL NO. HUGHES TOOL COM- PANY has available the following bulletins and films to assist you in getting your hole down in the shortest time and with the fewest bits: "H: ;' 'ulics for Jd~l~ Bits :,x,L~, "New Hughes Simpli- fled Hydraulics" B~g "Rotary Drilling "Best Constant W~t~ and Rotary Speed" "Care and Operation of Tool Joints" "Hughes General Cataj~g log" Motion Picture: search in Rock" Contact your Representative. He wi!l welcome the opportun- ity to work with you on yoq: ktwell and will furh.~~ you with the latest information rock bits an/d, dri techniques for area, compliments of HUGHES TOOL COMPANY HOUSTON, TEXAS U, S. A. LINER LINER ~ PUMP POWER ~ILL ~lP[ ~ TYPE DRAWWORKS POWER S I ZE 0 .D · ~ NUMBER 0 .D . I .D . LENGTH ACCUM WT. PUMP PUMP S P M MUD DULL. COND. FORMATIC NO. SIZE MAKE TYPE JET SERIAL DEPTH FEET HOURS ~T/HR DRLG. I00C R P M V[RT OPER- 32ND IN OUT HRS.LBS. DEV. PRESS ATION I 2 WT.ViS. W.L. T B G OTHER REMARK I I?'A ,, ,, ', ~-=~ ,, ~f~ 3ol J-/l ' · A 17~ /) ,, ,, ~ ,, ~a~ 70/ /~V~ -I-I · I~ 8 V~ H rc ~ p ~ /4~ e ~ ~ q ~ HTC 557 D REPORT OF SUB-SURFACE DIRECTIONAL SURVEY UNION O_TI., O~ CAT-!FORN!A COMPANY K.B.U ~3-8 WELL NAME KALIFONSKI BEACH ALASKA AL777-D8 LOCATION SINGLE SHOT 8/45/77 JOB NUMBER TYPE SURVEY DATE THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in 'our files for your convenience; however, should you so d~sire, all copies of tile survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in s~ric[est confidence. Additional copies of your survey report can be made from the original by any blueprint company. -COMPLETION REPORT ........................................................................... AUGUST'IS'," I977 UNIO,,~ OiL CO?..IPA¢,~Y OF ,.ALIFORNIA KoJ 13-8 '¢qAGN~TIC 5Ix~"~-~'~ . K. B .,e F r.;Ar~IL~S... ('}~ ¢~"~VA'rd~,,E~,,~, METHOD OF CONPUTATtON [)ECLI,N¢..TION 2~_ DEGOE. ES... EAST C(¢.,',PUTr:D FOR GLDDCO BY F.M.L[ ,r. ~,,r~ NdSEY ,~',~. ASSOC]ATES RECORu OF SURVEY ALL C^LCUEATIONS"'PERFORM[£D'BY I B ?, ELECT'RO't,ilC""'C(JF~PUTEF4 ............................... " TRUE' ........... ,*,:FAS'. DRIFT VERTICAL SUB .... DRIF'F' TOTAL'COORDINATES C L 0 £ U R E 5 'DE'PTi-t ANGLE DEPTH" SEA ............. DIREC DISTANCE ......... ANGLE . ,,, DEG. D ¢4 'O r,) 0 O,OO' -98,00 N T,OOW ..... 394 0 15 393~99 295.99 'tX 7.00W 0.,85 408 0 45 407.99 309.99 NSg'OOE -0,95 470 -2 45 "469.'96" '3T'1.96 ~N'20"OOE ................. 2'*'40 940 5 0 539.80 441 . ~0 ..... ' · , ~21-OOE 6 83 591 6 49 590 53 492.53 . ,', 7.OOE Ii,88 ~'..~ 655 9 15 653.90 '555.90 N!O.OOE 20.69 752 11 la~ 749.35 o51~ .35 N ,,r~.O0~ 37.73 906 13 O 899.90 80t.00 N 8.00E 69.77 N 12.54 E 102~ 14 ~5 1018.34 920.34 NIO.OOT 98.66 1153 16 45 11q8.64 1040.64 N13.r'~, . · ~ . ~ E _ ~,(.,~: 1~1 90 N "~3.~F 1277 !9 0 1256.65 !158.65 N]7.00E 166.66 N 33.73 E 1403 21 !5 1374.95 1276 95 Nl~.O{c 210 O0 1~:P5.,. 27 0 1486.24 1388.24. N~4. .OOE 257.90 N 60.50 E 1650 32 45 1594 59 ~496 ~9 "~ ~'~ _ 1777 ,~g 45 16~'7,6'1 159~ ..... . .... ~' .,.61 N1B~OOE 3~0"12 N 94.03 Iq44. 3R 15 1¢~28~ .31'i730.~'~.. N13.00E ' ~91.41 ,,," 117.~I E 2009 ~7 ]5 ].9~0.S6 ~852,S6 F~13.(,(._ 58'3,B'7 N 13t~.76 E 228T 36 45 2!01.00- 2003.00' NI3.00E .... 694.~]'N-' 164.2~- 2~T6 J6 O- 2253.18 -'- 2155.~8 '- N14".005 .... 803.~0"N 12.55 N t8 44 6 E 21'.'37 N 14 29 20 E 38,58 N 12 2-13 E 70.'38 N 10 11 46 E I'O0,13'"N 9 50 48 E 134.05 N 10 15 54 E !72.00 N 11 18 41 E 215.14 N 12 33 21 E 26a.91 N 13 12 12 ir: 327.13 N 13 2'7 O g 401~'29'"N .... i'3' 33 '6'-'E 505.24 N-'13 26 iT-'-E 600 - '': · 13 ,'~ 13 22 8 E ..... 713;27"N .... 1'3'18 37 E .... 825'-.-3~---i'~--i 3'-'20-' i~)'--'E DOG LEG SEVERITY DEG/iOOFf 0 · 000 0.063 3,b72 S r I0 O ~ oT AN 0, O 0.8 3°229 2,6 3,214 7.3 3.452 12.4 3.908 "-21"0 2.063 37,6 1.438 96.8 1-612 129,9 1.846 167.4 le789 4.761 ,7 _ ~.606 321.0 ..... 4.76-5 ............... 0.645 2591-37 -4 -- 2745 '40 ..... 1 25G7 t+l i 29'59 43 I 3123 '4~ 5 234.5'17 ....... 2247;17 ..... N16.00E ..... 869'.75'- N ........... 208'24 E ........... 894-;34-"-N 5- "24'04 .-~q4 ........ 2366 · 84- .......N!'7'. O'OE ....... 962 ,'67" N ......... 235.76'-"E ....... 99I';-12 ...... N .... 13- 45 -~O-"E ....... 1.646 ............... 973-":7 5 25-11-;81 -241'3-;'$1- NI7.0OE ....... I001.37-'i'4 .... 247.59 E-- I031"'5-3---N--i$ .... ~3--1-7"-'5 ....... 1.61~ lOiS'.-8 5 '262'-,;31 ....... 2526',"31 .... ,NI7.'OOE .... 1099.1'0 '-N' 277,47-5 --I'1'33';59-N -i'~%'-'10 ..... '6--E ..... 1.:~I6 . ' --- 111 5-,'-1 0 "27~3-.'03 .... 2545-,03 ...... N18'.OOE -'-I'?0'7;0I .... N' ......... 311'",ri-P-E ..... i246, 56-' -. RECORD OF SURVEY ALL CALCULATIONS PERFOP,;,'~ED BY ! F, f4 ELECTRONIC CO;,~PU'I'ER TRUE ............................................................... DOG LEG '" I'.'iE'. A S'~ ..... DR I FT 'VERT I CA'tZ ................ 'SU3 ....... DR ! FT ................. TOTAE""'COORD1NATES ..................... C'-'L""O"' '.~-"-:O--'i:('-"-E-"~S' ............... SEVER [ TY .SECT [ ~I'-- ... ~' D *~ .... nEPTH A.~GLE EPTlt SEA DIREC DI STA~CE ANGLE DEG/iOOFf DISTANCE O r4 DE G. D H 5 ..3280"44.' '--3320 '44 3603:59 0 3760 40 45 -'3~49 42 15 -'_~'41'33 4!- 15 'q'4'44'8" ~ 8'- 45 ?~762 .... 36" B0- 5~85 B1 45 569R '29 45 ~6009 26 ~0 6289 2S 15 6916 18 0 7~56 !~ ~0 7551 1~ 15 7~6 I¢ 45 8200 15 SO -" 8695 il 45 8770 !1 I0 ..... 30' '2855'49' '2757';'49 ........ NI'9','OOE ...... 13'10,;90'N ...... 306.26;'"'" .................... ~ "'1355'85 ...... N 10 47 ~5 E 0.446 133[,~'39 .... ~0 ..... 2884',0z ........ zvs-6','o'2 ......... ~I,);OOE ...... I3-'3-7-;~I N ......... ~55;:~8'-'E ......... i--SS'S'-,-SZ ~--i~-'"'-'52 ..... 5Z .... E ........ 0','000 ....... ~( ~...~ 3099.81 3001'Sl N32.00E 1498'.72-N' 440.~+6 E 'i'562,-I1'-N' I6 22 38 E 0.506 1546.37 ~ "' N ' ' , 3220*30 3ie~,':,,30 32-00E ....... t58-4'08 N '493 79 E' 1'659',26 N-'-I'! 18 48 E I 115 1646.16 "3361;'8'5 ..... 3'263;8.5 ...... N32;'OOE ....... I690';2'F~ ..... N 560.15"'£' 17'8"O;-6'8-'Tf-r8"'20" 6'E '(j'794 ............ i'77'0~'3'~- 34'99,!2 ..... 3401;12 ..... N32,OOF. ........ 1794'°19"N 62~°08- E ..... 1899":c]G'-11-'i9 12 28 E ' 0"~,,+3 .................. 37~0~ ¢'1 .......... ~'6'~ 2','4'! ' "a-:~'2";'O OE ........ 196~ ' 88'--"t~ - '73 Z ',S 7 "E ..... :' Z09 ?-;-8-7 .... N' '-'Z O'-'-Z~' ~ 6' E .... 0 '79"~,; .......... ZO~'Z ;--5'~-' - 39 ~ 9 ' 0'8'"--'".~"891-';'08 ...... t:4S"l' ,'0 OS ......... 21'2 9', ~ 2 .... ~ 832';'52" f:t ......... Z'Z-8-'6'"'2'~" ..... ~'" ~'Z ..... 2'1 ' ~ a a ............ 0 · 7'2 ~ ........ 2'Zg2 4243.86 4145.8& NgI,t')OE 2283.65 N 925.26 E 246-3.98 N 2Z 3 22 E 0.801 ~505,04 4407.04 NBI,OOE 242~{.35 N 1012,20 E 2630.86 N 22 37 B9 E 0,723 4774' 02 .... 4'676"02 5048°26 4950°26 NSO,OOE 5302.25 52,04.25 N29.OOE 5593.~6 5'495.36 "N2 9.'O'OE 5~88.60 5790.60 N27.00E 6192.51 6094.51 NZS.00E 6/-,,91.45 6393.45 ' N28.0OE 6809.i3 67ti,i3 N28'00E 7109.. 17 701!'° 17 N26.00C 7590,:1'6 .... 7492'"1-6 "HZS"-OOE 7,553-.'66 .... 7565.66 .... N27.00E" N31.OOE- 2555',52" N 1094.62_' 2691,82 t',~ 1169.01 2794..31 i"~ 1227.00 2897','18 ~' 298.g. 85 N 1332.77 3077°74 N 1379°04 3165,41 ~ 1425,66 3~59o27 N 1475.56 ~341 °64 N !517.5B 'B'4a~', 51 N 1570-,45 ~5B'.-73 ~. 1577.3~ L E F. E 3471,65 N 24 14 46 3577,73 N 24. 21 27 E 3670,07 N 24 25 Z6"E 3786',5'4'"-'N-2~'-'30 IZ E 3801'42 N 24 30 '54 E z,o47 0.796 _ 0.88 1 327Z.4Z 0,159 337Z,50 O.07P 347 0.149 357,. 1 1.036 367D"07-' "0 · 758 37'8'6'* O, 775 3501,4'Z- '"~OTTO~"I'-HOLE CLOSURF "3[~O],.4~""F"EET 'AT N"-2/+' 30 54 F 'CODE r,! A M E IF;TERPOLATE[)"TRUE VERTICAL D[:PTHS, COOR. DI/.4ATL5 AND CLOSURES FOR GIV[LN DEPTHS TR~E ME'Ac''~=~o~,,,-~.,.` ..... WCRTICAL~,. .......... TOTAL-''CC~RDINATES C"L O'"S' U R E 2EPTFt DEPTH [) I STAF.¢CE ANGLE D M S . . v"'A- 8 SA,ND A-O .:>AN v"A- 10 SAND A-Il -SAND B'I SAND .q..-4 SAND 6-5 SAND C-]. 'C-2 SAND 'TOP BELGA TOP TYONEK 75-8 SAND 4330 3648,,99 1.902.61 /'4 692.83 E 2024.84 4389 ' '3694,,54 1934.',Z,:i "N' 712.70 "E" 2061,.52 447.6 3731,05 1959'51 ¢'4 728,39 4528 ..... 3803o05.. 2008.14 N 751%,64 F 2146oo7 4620 ........... 387'5.69 2056';22' N ................... 788.22 "E 2202. t2. 4,68'4. 3926.6~ .... 2089' 33'"'N ...... 808.39 g 2Zq0.27 4759 ..... 3986'"57 [,,1 20 0 32 E Fl 2O 13 32 g N 2.'O 23 28 E N 20 ~! 45 E 2127"79 .... ' ............... ' ........... ' ...... ~ 84 N .,'53~.60 L ,:2, ,52 ' N"2i" ~i:)~'9 .... E ).~0 · 99 3596 · 54 .3633.05 :3705.05 :3777.69 3828.61 3888.57 4 gq 0 ................. 40.5'2., (34- 5062 5569' 5659 892.8 ~i 664 ' [377.0 "::4562 o48 4740.20 72'32.80 75r~:9,,82 7663,66 216'5' ,'7 9"' N ................... 856.24; ' 2277.90 N 2436.45 N'- 1017'07 2509.'g6 N ........ i06!,23 2548'86 'N 1084.61 3371,37"'N ' 1552,20 3Z~39.88 t,I ..... 1567.4,5 3458,73 N 1577,3:3 t.'{ ............ 23~.,1 * 70 .... N" 21 ~32 '3,9 E"' :3954 · 04_ C '' 2457.3q, :N 22 1 54 E 41'35.91 ,'., 22 27 E 4422.35 E 264:0'.21 "'- ' 39 E'- 2725'*09 ..... N"~2'2 ..... 55" 8 E 4564.4,8 E '2770,04 '-N '2'J3 3 ~ E 4.642,20 E "3'703,22' N-2~'-"26 25 E 7L3~,80 .. E 5780'"]T N 2t~ 29 50 E '146Z,82 {:Z S801.42 N 24 30 54 E 7565.66 DEPTH AND OTHER DATA FOR~'EVERY EVEN 100 FEET OF $U6 SEA DEPTH. r,,t ASU.'- _ . ..... TRUE h1E:ASURED VERTICAL SUB ND-TVD VERTICAL ~EPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES' '~ . ,~ ~,. 198,' 298.' 399. 498° 698, 798, .......... 898, 998. 1.098, 1198,' 1298., -1398 · 1'498. 1598. 1.698. '"1798, 1898, 1998, 209g. 2198. 2298. 2398. 2]-.,,98. '2598. I00 '200 300 400 500 600 700 800 1000 1100 1200 0 0 '-0.21"¢1 ........ O*OZ ..... 0 0 ............. 0'"4 8 ' N ............ 0 · 05 0 0 0,87 N 0.10 0 O 3.86 N .... 1.65 0 ...... 0 ..... i2.78 N 4.1~ I 1 28,13 N 6,~9 3 47.56 N 9.42 .......... 6 ............................ 3 ............... 69.32 N 12,48 8 2 93,44 N 16.22 12 ..... 4 .... 120,'21~ N 2t,31 17 5 ~- 149.81 N .... 2b,35 22 .... 5 182,61 N 38,05 1300 .... 29 ..... 7- ' ..' ........... 2i8.87 N 49.~8 1400 ....... 4¢, ....... I1 26,3.69 N 61.95 1500 56 i6 320~25 N 76,65 16.00 7~ 23 390.12 N 94.03 1700 107 "~.'~8., ...... 467.85 N 111.97 1800 134 27 . 544,16 N 129..D9 1906 160 26 " 618.~,1 N 14,6.78 2000' 185 25 ~-6'9~',78 H 163.67 2100 210 25 ' '7'f~. 98 N 180.75 2200 233 23 835,30 N 198,70 2300 260 27 909,63 N 219,84 2400 290 30 989,85 N 244,07 !075.62 N' 270,29 2500 "2698', .... 2600 "2798' 2700 '2898. 2800 2998. ........ 2900 3098. 3000 325 35 ..... 362 .................... 37' "40t 39 441 ..... 40 ....... 474 .................... 3 ....... 502 .............. 2 ...... 1165,:~5'N ........... 298'15 12,5.7'26 ,"4, 32.8.0,% "1350.17 N 359.96 E E E E E E E. E E E E E l::'b t98 298 398 498 ...... 599 700 802. 1007 !111 1.215 1321 ' ' 142..8 1538 1654 1777 1905 2032 2158 22~ 2408 2532 2789 2923 · ' '3060 3199 3339 ...... .~ Z. n,,~ .... 3601 ........ 3730 .......... 3198. .... 3100 ..... 532 ..................... 3 .......... 3863- ................ 3298, ..... ~2'00 ....... 565 ....................... . . 0 ............... 1567.54 N ...........483.'45" E .......... 3998 ............... 3395, .......3:300 ........ 600: .................... ~5 ............................ 1718' O0'--N '5'77 i-4 T- E ...... "4131 ................ 3498¥ ........ 3400' 633 33 ....... 1793.06' ;'q ..... -62't;;-:~ 8'- E ..... ~ ............... ' ........... ..... 4263 35'98; ......... 3500 .... 66'5 .................................. ~2 ....................... 18 66,40"-r'l ............ 670¥2'0'-E' ......~ ..................... ...... 1428, 79~ N .......... 3'9'7-,-64' E .............................. ......... ~497.47 N ......... 439¥68-[{ ~ "'~.'iEASURED D[:PTH AND OTHI:.R DATA I.-':OR EVERY EVEF,~ 100 FEET~..r'""' SUB SEA DEPTH ................................................... TRUE ...................................................................................... z cA.~UR.:. D VERTICAL SUB D-TVD VERTICAL ." COOR D l NATE 5 DEPTH DEPTH o~A DIFFERENCE CORRECTION TOTAL 4:39 .... 452 464 477 ..... 501 '" 525 5377 5494 5610 5'726 5~40 5953 60,64 61'75 6234 6.393 6501 6608 6715 6P26 7031 ........ 72fl~ 734 7 745 755 '766 776 ..... 787 7q80 3 369~, 3600 695 30 1936.80 N. 714,19 E 2 3798*' 3700 .........724 2") ....... 2004','7 ''~ ................ *" ...... ~'t:- 8 3898. 3800 750 26 2076,79 N 797.12 E S 3998. 3900 775 25 2134.96 h.l 835,91 E 7 .... ~f098. ...... AO00~ ............ 799 .......................... 24 ........................... 2197.05 'N ...............873*22 ~' .. 9 ......... 4!98~" 4100 ....... 821 ........ 22 ..................... 22~6.~Z' 'N ............. 909.19 E O ................4,~.~8. ....... ~200 ............. 84! ........................20 23i'~,68 ..~i .......... 943.90 E ............ 4'398 4498 .... 4798 ......... &,~98 ....... 4998 .~ 5098~ 5t98o 5298 · 5398~ 5498. 5598 o 569~, 5798. 6098 -- , 4400 $79 · 4500 896 · ..... 4600 .... 912 · ..... 4700 928 · ....... 4'800 ......... 942 .... 49'00 ...... 955 ............... 4300 ........... 8'60 .............................. 19 ..................................... 2370,56 N 977,4'? E 966 977 '986 ¢95 1003 1010 1017 !022 1027 1033 1038 5000 5100 5200 5300 5400 5500 .... 5600 5700 5500 59O0 600~ 19 17 16 16 1~ 13' 11 11 8 7 5' 6 2424"61N 1009.95 . 2476,99 N 1041,43 2527,85 N 107!,99 2577°20 N 1101,63 2624,59 N ......... i129~80 2'669.86 N 2713.0~ N 1181,20 2753.~7 2792.58 N .... 1226,04 2829.5~ N I246,55 E 2864,91N 1266.13 E '2898.72 N "1284.87 E 2931o08 N 1302.54 E 2962.03 N I318.95 E 2991.57 ~ 1334.15 E 3020.62 N 1349.09 E ~049.~0 N 1364.28 F ..... 6'19..9, 6100-- 1044 .... 6' 30.79'.3'6--'N ..... t;.~79.90 E 6298,-" 6200 -1049 5 310~.77 N 1395.53 E 3 6398. -' 6.'300- ' 1055 '- 6 8 6498. ...... 6400 ..... 1059 ............ 4 ...... 3167.32- N ...... iP26.67 "E' __ 3 -' 6598," ' 6500--1065 ..................... 6 ...... 3196,52 N 1442.19 E 9 .................. 669B; ........ 6600 .......1070 ..................... 5 ................. 3226". i 3'--~ .........1~57.94" E ...... 4 ...................... 6798; ...... 6700 '--1076 ............................. 6 .......................... 32 55", ~-7-71 ........ i4-73'. 7'5'-' E ............................................ ............... 6898; ........ 6800 .... ]082 6 3485.24 N 1489.20 699ff~ ........ ~ ................... '~ - .................. 7OVa'*' ......... 70GO 1090 ............................... 4- - .......... _ . .............. ~'.t[! A et'':':'''' ' ' F'_'P . "' ' ' - r'"' ,'", , .:,.~,..,.~.~ D TH ' AND ' (:) ~ HER DATA'FOR £VERY' EVEN 100 F t:.r:~ OF' ,SUI3 5L,~,\ b[PT'i:i. ................................. TRUE ?,"~[:.':ASURED VERT I CAL SUB, HF)-'TV~, VERT I CAL DEPTH DE[,'"' ~ ~F, SEA D ~FFE'RENCE CORRECT[ON TOTAL COORD ~[NATE$ ........................................................................ 8292 7198. 7100 1094 4 ~363.22 0395 ........ 7298' ............. 7200' 1097 ......................... 3 ..... 3'38'6.2i ~49~ 7398" 73 '" . . .0,) It00 3 3407 82 N 1590.67 2601 7498. 7400 1103 3 342S.06 N t561.20 ~703 ...... 7598;' ....... 7500'-- 1105 ................................2 ............................. 3446.94 N '-'1571.21 -"INT[;RPOLATED 'VALUES -FOR EVEN !000 FEET OF tflEASU[i~.E.(} DEPTH, f'~E~A.~URE'D VERT ! C/',L SUB ............. ~,..PTH DEPT~..I SEA TOTAL COORDINATe S 1000 ..... 991. 893, ..... 91.73 N 15o93 Fi 2000 1872, 1.774. 525.06 r,,l .tZS,, 18 3000 2654. 2556. 1125,99 ~ 285,76 E 4000 ........... 3399; 3301, ........... 17i9.29-' ~ 578.28 'E 5000 4182. 408z,. 2247.91 ~,4 903,78 6000 5040. ~942, 2688.33 N 1167,00 E 8000 ......... 691.7. 68!9. 7'000 ............ 5968' 5'8"/0. ..............3012'05' ' '3290',7t+ N" 1492,,04"'"E .... VERTICA'L "SECTION .... ' SCALE I"=1OOO' UNION OIL COMPANY OF CALIFORNIA KBU 1:3- 8 RADIUS OF CURVATURE MAGNETIC SINGLE- SHOT .. ALL DEPTHS.S ARE TvD.- ' "' . · . 4~)0' 3200 7200' 68~ 6400- HORI' ITAL VIEW . SCALE I": 500' UNION OIL COMPANY OF CALIFORNIA KBU 13-8 RADIUS OF CURVATURE MAGNETIC SINGLE- SHOT TVD= 7664 TMD= 87.70 ' 2800 2000. ALL DEPTHS SHOWN ARE TVD. ' 30, ~77 ~. Jim ~l~r Dis~ict Drill~ ~i~t~nd~nt ~ic~ Oil ~ P. O. ~6247 Ancho~ Alaska 995~ It ~ ~ ~ht to ~ attention that in t~0 recent cases work has ~ ~ ~n w~/is without prior approval frc~ our division. The ~ ~lt~a W~ll was ~lrilled to 8770' when ~ pemmitted depth~-8200' M.D. In the Trading_ Bay Stat~ A-20 well ~ plug ~ ~ of y~r ~a~ had already ~ ~leted by th~ ~ w~ had received ~ w0rkover program.. li~ to ~1 ~ to your attention since penalties will be ~~ if ~s practice c~t~nues. Attac~ are appr~¢ed copie~ of ~ .~)tice form. 10-403 for ~ ~ w~lls although in ~ case approval is after the fact. ~losures Union Oil and Gas [""'sion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99r502 Telephone' (907) 279-7681 .. l.. union September 20, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 Dear Mr. Hamilton' Enclosed for your approval is a Sundry Notice form for Well #KBU 13-8, Kenai Gas Field. Sincerely yours, ~ Ji~R. Callender "~T~t, Drlg. Supt. Form 10-403 REV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals,) O,L F-1 ~AS [*X-1 WELL! i WELL OTHER 2_ NAME Of OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR P. 0. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL 10. At surface 804'S & 675'W of the NE Corner of Sec. 18, t4N, RllW, S.M. ~. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 12. KDB 98' above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20304 6. LEASE DESIGNATION AND SERIAL NO. ADL-22330 7. If INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kenai Beluga Unit 9. WELL NO. KBU 13-8 FIELD AND POOL, OR WILDCAT Kenai Gas Field SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T4N, RllW, S.M. PERMIT NO. 77-29 }ort, or Other Data NOTICEOF INTENTION TO: TEST WATER SHUT~Z)FF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (bt,.,) dril 1 ing deeper (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The well was permitted to drill to a total depth of 8200'TMD and 7425'TVD. Due to the directional program employed and encountering of potential producing zones deeper than anticipated, a total depth of 8770'TMD and 7664'TVD was required to adequately penetrate potential pay for testing. 9 5/8" casing was run to 8669'TMD and cemented with 3000 sx. ClasS "G'" cmt. with additives on 8/7/77. 16. I hereby ce[t~fy that the foregoing Is true and correct ., , . DiSt. Drlg. Supt. DATE 9/19/77 (this space for Stat~j0fflce use) CONDITIONS ~O~A~P~VAL. IF ANY: See Instructions On Reverse Side · ,-o ;: ?;.-: ..: ,,~o,,,,. . ..: Htrr]r Ku. zl~;?:;.!; Bob. Wu, then -. AT ;" '~': ' ' AT :..: ::~:-,.. · ..... .. ;.... · . ::.;:.....:' ... · . .. :~..~'~'~::: , TRANSMITTING q' I'~ F'. ~LLOW! NG: ~-. ~-.- ' ' ~ -~: .. ..~ ,., ,:_~:.. 1 se~i:~;w4m]:Led & clued c~g ~z~mwe~.. ., -~ . . :~,'!" '.; .,,!. ~: ..r. ".' :?'-. · : '-:- .. ,.-~.;.:~ .... - .., :.,:, ~ :::_',:::.~,:,..': . - ,,~.~., .: .. : · .,.. ' ,..: :'.V?~.. TBS!:~,~O:i' '.' ' ,.,~>..~. :, ,,. :.; . , ?;.': . x . ...-;;'-,..,.. . · .., ..... · - ..... , ,,, %-~:¢:?:¢~ '. '. "::' :~.::,:;-~:" -.. : - :. :....:.,.:: · :.. .. ,; '..' .; A....-,' - . . . '; ~. . ;,.,7 -..-'....,,.,:'..:. .. . ' ~:.. .~' . ~ ~-.... :'~ ... . . . . '... . .:::,. . , ,,, -'. ' ~:' '. :' . ., ~. . ,. . ~;'.: . -, ,, .. FORM 1-2M02 (REV. 11~2,} PRINTED IN U.S.A. ..' :~'.;.'.- .~. Union Oil and Gas I _don' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union September 12, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive- Anchorage, AK 99504 RE' TBS A-20 TBS A-32 5 FI',J("; [ ? (-, Fr')L .. 3 C;[:OL FFV - . . D P A F T SFC (TC~Nf ! :,,: Dear Mr. Hamilton' Enclosed for your information are three (3) copies of the Monthly Report of Drilling & Workover Operations for the above captioned projects. .. Si ncerely :your.s, ( ....dim"R. Cal lender Disd. Drlg. Supt. CC' USGS Harry Lee Marathon Oil Co. 14 15 16 17 Form No. P-4 REV. 3-1-7@ SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP1 NUMERICAL CODE 50-133-20304 6. LEASE DESIGNATION AND SERIAL NO. ADL-22330 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL [--] GAS ~-~ Kenai Beluga Unit WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Union Oil Co. of Calif. KBU 13-8 3. ADDRESS OF OPERATOR 9.WELL NO. P. O. Box 6247 - Anchorage, AK 99502 KBU 13-8 4. LOCATION OF WELL 804'W & 675'W of the NE Corner, Section 18, T4N, RllW, S.M. KU 41-18 drilling pad ~?"~ 7"i~?'~i!~,:r.~-.,~- ,'. ii/ ..... ~, SEP ! 4 !977 10. FIELD AND POOL, OR WILIDCAT Kenai ~as Fi eld 11.SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 8' T4N, RllW, S.M. 12. PERMIT NO. 77-29 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOL 'g~¥'~AC~N 'A~ L~aL~8$~I~'e~LUDINO DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOB~:~!.~3~. ¢~(]~rlOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 8/1/77 6353'TD, 13 3/8" csg 02505' (Footage 724'). Drlg & surveyed 12 1/4" hole from 5629' to 6084'. Had gas cut mud at surface. Circ. out gas cut mud - no fl ow. Drlg from 6084 to 6314'. Pooh for new bit. Had tight hole from 6314' to 4912' - 35-40M# excess drag. RIH w/ 12 1/4" bit #6 on BHA #12. Drlg from 6314' to 6353'. 8/2/77 7O70 'TD 13' 3/8" csg. 02505' (Footage 717'). Drlg and surveyed 12 1/4" hole from 6353' to 6969'. Pooh to change bit and BHA. Tight hole pulling to 250M# from 6315' to 6504'. Ran 12 1/4" bit #7 on BHA #13 on 5" DP and drilled from 6969' to 7070'. 8/3/77 8/4/77 7876 'TD 13 3/8" csg 02505' 8317'TD 13 3/8" csg. 02505' (Footage 806' ) 7876'. Drlg and surveyed 12 1/4" hole from 7070' to (Footage 441'). Drlg and surveyed 12 1/4" hole from 7876' to 7916' Pooh for new bit. Ran 12 1/4" bit #8 on BHA #12 and drilled and surveyed 12 1/4" hole from 7916' to 8317'. 18 19 8/5/77 8/6/77 8720 'TD 13 3/8" csg. @2505' 8770 'TD 13 3/8" csg. 02505' 20 8/7/77 8770'TD (Footage 403'). Drlg and surveyed 12 1/4" hole from 8317' to to 8720' Circ. and condition hole for logs and pooh. Schlumberger ran CNL-~R, BHC sonic, and DIL from 8711' (loggers TD) to 2505'. (Footage 50'). Ran RR bit #3 on BHA #12 and drilled 12 1/4" hole from 8720' to 8770'TD. Circ. and condition hole for 9 5/8" csg. and pooh. Changed rams in BOPE to 9 5/8". (Footage 0'). Ran and landed 216 jts 9 5/8" 47# N-80 butt csg. certi~X, Rat tt~/foregoina/is/trdand corr~dt _ 14.Iheteby ~' ' ' ' Dist. Drlg. Supt. 9/12/77 SIGNED. ~~~ ~~ ~ ~/dTITLE DATE ~OTE--Report on this form is required for each :alendar momh, reBardle~ o~ the status of operations, and must be filed in dupli:ate wi~h 1he oil and oas conservation committee by the ~5th of the sue:eedin9 month,unl~ otherwise directS. 13 3/8".csg @8769' w/ float collar @8726'. Broke circulation w/ 500 psi in @2505' 1/4 hr and circulated bottoms up. Preceded cmt w/ 200 cu. ft. 9 5/8" csg. fresh water. Cemented w/ 3000 sx C1 "G" containing .75% D-31, @8769' .3% D-19, and .1% D-6 mixed @l l 6#/cu. ft. Displaced cement to ETD 8726' float collar w/ 640 bbl mud and bumped plug w/ 4000 psi. Released (float collar) pressure and floats held o.k. Cement channeled w/ returns to surface after 550 of 640 total bbl displacement pumped. CIP @6:00 p.m. 8/7/77. Hung 9 5/8" csg. w/ 150,000# and removed BOPE. Installed OCT 13 5/8" 5000 X 10" 5000 psi tbg. spool. 21 22 23 8/8/77 8/9/77 8/I0/77 8770'TD Finished nippling up tbg. head and tested to 5000 psi. Nippled up 8726'ETD 12" 3000 psi BOPE and tested to 3000 psi. Ran 8 1/2" bit #9 and (float collar) and 9 5/8" csg. scraper on BHA #14 to top of cement @8642'. Unable 13 3/8" csg. to move 5" DP @330,000#. RU circ. head and circulated out cement @2505' contaminated mud. 9 5/8" csg. @8769' 8770'TD Finished circ. out contaminated mud. Drilled out cmt. in 9 5/8" 8726'ETD csg. from 8642' to 8715' F.C. (DP meag). Circ. & cond. mud for (float collar) logs. Pooh. GO Int. ran GR-Neutron Aeoustic Signature cement bond 13 3/8" csg. log from 8711' !,~TD) to 2400' Ran 9 5/8" Baker retrievamatic @2505' squeeze pkr on~ DP and set ~8200' to sqz. for zone isolation 9 5/8" csg. above Tyonek Section. Test DP and pkr to 1500 psi. @8769' 8770'TD 5630'ETD (cmt plug) 13 3/8" csg. @2505' 9 5/8" csg. @8769' Finished testing 9 5/8" squeeze pkr @8200' and 5" DP. Perforated 4 HPF 8308' to 8310' for Tyonek zone isolation squeeze. Broke dwn. perfs #3200 psi and pumped in @11 cu ft/min & 3800 psi, Squeezed perfs 8308-8310' w/ 150 sx. C1 "G" containing .75% D-31 6% D-19 1°/ · , . . ~ D-6 to a final squeeze pressure of 4000 psi Displaced cmt. to 8260'. Reversed hole clean and set pkr @7475'. Perfed 4 HPF 7568-7570' for Beluga zone isolation squeeze. Broke dwn. perfs @2200 psi and pumped in @ 13 1/2 cu.ft./min & 3000 psi. Squeezed perfs 7568'-7570' w/ 150 sx. C1 "G" to a final squeeze pressure of 2900 psi. Reversed hole clean and set pkr @6194'. Perfed 4 HPF 6298'-6300' for Beluga zone isolation squeeze. Broke dwn. perfs @1200 psi and pumped in @24 cu.ft./min & 2000 psi. Squeezed perfs 6298'-6300' w/ 200 sx C1 "G" to a final squeeze pressure of 2600 psi. Displaced cmt. to 6250'. Reversed hole clean and set pkr @5566'. Perfed 4 HPF 5658'-5660' for zone ~solat~on sqz. above ~eluga, Broke'dwn. perfs-~llO0 psi & pumped in @30 cu',ft,/min. & 1800 psit Sqz. perfs 5658~5660'' w/ 200.sx. C1 "G".containjng 1% CAC12,,75% D-31, .6% D-19, .1% D=6 to a final sqz pressure of.1800 psi, Displaced cmt. to 5630'. Reversed hole :clean and set pkr @5'286', Perf 4 HPF 5398' to 5400' for Sterling zone isolation sqz. 24 25 26 27 8/11/77 8/12/77 8/13/77 8/14/77 8770'TD 7518'ETD (cmt. plug) 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 5350'ETD (sqz cmt. ) 13 3/8" csg. @2505' 9 5/8" csg. @8769' Finished pef 4 HPF 5298'-5300' for Sterling zone isolation sqz. Broke dwn. perfs @1200 psi and pumped in ~32 cu.ft./min & 1600 psi. Squeezed perfs 5298'-5300' w/ 200 sx. C1 "G" w/ .75% D-31 .6% D-19, .1% D-6, 1% CaC12 to a final pressure of 1400 psi. Reversed hole clean and set pkr @4970'. Perf 4 HPF 5058'-5060' for Sterling zone isolation squeeze. Broke dwn. perfs @1200 psi and pumped in @ 28 cu.ft./min & 1900 psi. Squeezed perfs 5058'-5060' w/ 150 sx. C1 "G" w/ additives as above to a final pressure of 1350 psi. Reversed hole clean and set pkr @4726'. Perf 4 HPF 4820'-4822' for zone isolation squeeze above Sterling. Broke dwn. perfs @ 1000 psi and pumped in @ 36 cu.ft./min & 1800 psi. Squeezed perfs 4820'-4822' w/ 200 sx. C1 "G" w/ additives as above to a final pressure of 1300 psi. Reversed hole clean and pooh w/ pkr. Ran 8 1/2" RR bit #9 on 'BHA #15 and drilled out squeeze cmt. from 4734' to 7518'. Finished drlg out squeezed cmt & clean hout hole from 7518'- 8719' and circulate to cond. mud. Pooh w/ bit. Ran 9 5/8" Baker retrievamatic squeeze pkr on 5" DP and tested zone isolation squeezes: Squeeze No. Zone 1 Tyonke 8308'-8310' 2 Beluga Zone 1 7568' -7570' 3 Beluga Zone 2 6298'-6300' 4 Top Beluga 5658'-5660' Test Grad. 1.03 .92 .85 .85 No. 5 squeeze in Sterling Zone #1 5398'-5400' leaked @.85 grad. and held .72 grad. Pooh w/ pkr. Ran 9 5/8" Baker retrievable bridge plug and retrievamatic pkr on 5" DP. Set RTBP @5530' and tested to 2500 psi. Spotted 24 cu.ft, sand on top of RTBP and set pkr @5299' Broke dwn. Sterling Zone #1 squeeze perfs 5398'-5400' @1100 psi and pumped in @28 cu.ft./min. & 1800 psi. Resqueezed perfs 5398' to 5400' for isolation of Sterling Zone #1 with 300 sx. Class "G" w/ 1% CaC12, .75% D-31, .6% D-19 and .1% D-6 to a final pressure of 1800 psi. Held pressure on squeeze 1 hr and reverse out. WOC 3 hrs and attempt to test squeeze but pkr would not hold. Had full circulation both reverse and conventional but could not move pkr. Backed off 5" DP @5134' and left in hole 5 jts 5" HWDP and retrievamatic pkr. Ran screw-in sub on jars & tied into top of fish ~5134'. Circ. & jarred on fish - unable to work fish free. RU Dialog - ran free pt. Fish 25% free to top of packer @5290'. B.O. DP @5165' & pooh. Ran R.S. on 5 jts of 8 1/8I' O.D. washpipe. Tagged up on cmt. opposite #6 squeeze perfs @5058'-5060'. Reamed to top of fish @5165'. Washed over DP and C.O. to top of packer @5290'. Pooh w/ washpipe. Ran screw-in sub. Tied into top of fish @5165' & pooh. Recovered total fish. 8/15/77 8/16/77 8/17/77 8770'TD 13 3/8" csg. @2505' 9 5/8" csg. @8769' All fish recovered. Ran 9 5/8" Baker retrievamatic & set @ 4968'. Tested zone isolation squeeze #6 in Sterling Zone #2 5058'-5060' to .8 grad. Moved pkr to 4689' and tested zone isolation squeeze #7 in top Sterling Zone 4820' -4822' to .8 grad Pooh. Ran 8 1/2" bit #9RR on BHA #15 and drilled out squeeze cmt. 5329' to 5516'. Circulated hole clean and washed sand off RTBP @5535'. Pooh. Ran 9 5/8" Baker retrievamatic & set @5328' Tested Zone isolation squeeze #5 in Sterling Zone #1 5398'-5400' to .8 grad. RIH and could not retrieve RTBP @5535' Pooh and laid dwn. pkr. Ran Baker retrieving tool on 5" DP and cleaned out to top of RTBP @5535'. 8770'TD 8718'ETD (fill on FC) 13 3/8" csg. @2505' 9 5/8" csg. @8769' Finished cleaning out to RTBP @5535'. Retrieved RTBP and pooh. Ran 8 1/2" bit #9 RR on BHA #15 to ETD@8718' and circ. hole clean. Displaced entire mud system w/ fresh water and mix salt to raise weight to plus or minus 70#/cu.ft. 8770'TD 8718'ETD (fill on FC) 13 3/8" csg. @2505' 9 5/8" csg. @8769' Circ. w/ DP @8718' and conditioned WO fluid w/ addition of salt, CaC12, and Dril-S. Pooh w/ DP. Ran 8 1/2" gauge ring and junk basket on W.L. and could not work below 5300' (washed over Baker retrievamatic set @5298'). Ran 8 1/2" bit #9 RR and 9 5/8" csg. scraper on BHA #15 and worked scraper from 5244' to 5346'. RIH to 8718' and circ. btms. up. Pooh. Ran 8 1/2" gauge ring and junk basket on W.L. to 8300'. Ran 9 5/8" Baker Model "FA" pkr w/ 7"x9' millout extension, 4 1/2" x 12' pup jt, and Otis 3 1/2" "×N" nipple tail. Set on W.L. @8250' w/ btm of pkr tail @8277' 8/18/77 8/19/77 8/20/77 8/21/77 8770'TD 8718' ETD -(fill on FC) 13 3/8" csg. @2505' 9 5/8" csg. @8769' Finished setting perm. pkr @8250' and RD W.L. tools. Ran 6"x4 1/2" x7' Baker seal assy on 5" DP and spaced out in pkr @8250' Hooked up test manifold and separator and tested to 3000 psi. Tested 5"x9 5/8" annulus and pkr to 1000 psi. Pulled out of pkr and used 1200 psi gas pressure from #41-18 to blow DP dry to 2400'TVD. Stung into pkr @8250' and released gas pressure. GO Int. differentially perforated Tyonek w/ 4 HPF using 2 1/8" torpedo link-jet expendable gun 8334' to 8364' and 8660' to 8680' w/ now flow or pressure increase (hydrostatic pressure 2850 psi). Pulled out of pkr and circulated hole w/ WO fluid. Pooh. Ran HOWCO 9 5/8" RTTS pkr and testing valve on dry 5" DP and set @8205'. 8770'TD Set 9 5/8" RTTS test pkr @8211' on dry 5" DP to DST Tyomk 8245'ETD(ret) perfs 8334' to 8680'. Opened tool w/ surface valve shut in 13 3/8" csg. and pressure increased to 2100 psi in 6 1/2 hrs. Opened well @2505' thru test equipment and tested for 3 1/2 hrs @ rates of 96 to 9 5/8" csg. 162 MCFPD w/ 55 psi flowing surface pressure. Released pkr and @8769' circulated hole w/ WO fluid. Pooh and layed dwn. test tools. Well started flowing and shut in w/ 150 psi. Stripped open ended 5" DP in hole thru hydril and circulated gas out g3900' and 8235'. Circulated hole thru SWACO choke and displaced w/ fresh water. Circ. to condition WO fluid. 8770'TD Pooh. Ran and set 9' 5/8" cmt. retainer on W.L. @8245'. Ran 9 5/8" 8245'ETD(ret) Baker retrievamatic test pkr and stimulation valve w/ 500' 13 3/8" csg. of water cushion on dry 5" DP and set @7510'. RU test equipment @2505' and tested to 3000 psi. Dry tested cmt. ret. - held o.k, GO 9 5/8" csg. Int. ran 2 1/8" perf tun to perforate Lower Beluga and could not @8769' get below stimulation valve. Released pkr and circ. hole w/ WO, fluid. Pooh and removed stimulation valve. Ran 9 5/8" test pkr to 7510' and used 1400 psi gas pressure from #41-18 to blow 5" DP dry to 2800' TVD. Set pkr & GO Int. differentially perforated Lower Beluga w/ 4 HPF using 2 1/8" tornado jet-link expendable gun 7578' to 7628'. 8770'TD Well unloaded and cleaned up bypassing surface test equipment 8245'ETD(ret) for l0 hrs. Tested well for 10 hrs at .9 to 1.8 MMCFPD rate 13 3/8" csg. w/ 10 to 20 psi flowing surface pressure making minor amounts of @2505' water plus or minus 4 BBLS/day. GO Int. differentially perforated 9 5/8" csg. Lower Beluga w/ 4 HPF using 2 1/8" tornado jet-link expendable @8769' gun 8202' to 8218', 7892' to 7916' and 7840' to 7865' 35 36 37 38 8/22/77 8/23/77 8/24/77 8/25/77 8770 'TD 8245'ETD (ret) 13 3/8" csg. @2505' 9 5/8" csg. @8769' 8770ITD 8245'ETD (ret) 13,3/8" csg. @2505' 9 5/8" csg. @8769' 8770'TD 7509'ETD (ret) 13 3/8" csg. @2505' 9 5/8" csg, @8769' 8770'TD 7509'ETD 13 3/8" csg. @2505' 9 5/8" csg. @8769' With 9 5/8" test tool set @7510' perforated the remaining lower 1/3 of the Beluga (test Beluga Interval #1) using 2 1/8" OD GO Int. tornado jet-link perf gun. Tested well & unloaded rathole fluid - attempting to stabilize well. Making plus or minus 4.0 MMCF/day - still unloading rathole fluid & mud. Prod. rate increasing as water unloaded. Stabilized lower Beluga test interval #1 (perfs 7578' to 8218') @4.25 MMCF/day. Shut-in well & ran Hewlitt-Packard gauge & pQsitioned @7875'. Re-stabilized rate @5.0 MMCF/day. ~low pr'~ss, mid-perf~ 439 psi. Stabilized well @ pipe line system conditions w/ 890 psi surface pressure (1047 psi BHP flowing). Well made 4.15 MMCF/day @ pipe line conditions. Shut-in well for BHP build up survey - 5 hrs. BHP = 2830 ~i Pressure, build up showed minimal formation damage. Killed well after testing lower Beluga test interval #1 from 7578' to 8218'. Pooh w/ Baker retrievamatic. RU GO Int. Ran 9 5/8" Model "K" cmt. ret. set at 7509'. RD GO Int. RIH w/ 9 5/8" Baker retrievamatic set at 6260'. Blew DP dwn. w/ 1300 psi of gas from #41-18. RU GO Int. Perforated Middle Beluga test interval #2 from 6344' to 6384' w/ 2 1/8" tornado jet-link expendable gun. Well had good blow after shot Flow tested Middle Beluga test interval #2. Fluid level standing @1200' w/ perfs open from 6344',-638~'. Added perfs, i'n Middle Beluga test interval #2 using 2 1/8" I.D. GO Int. tornado link perf gun as follows: 7244 -7264 7040 -7076 7004 -7018 6852 -6882 6820 -6845 6790 -6804 6466 -6474 6446 -6458 Flow tested well. Fluid raised slowly to 350'. Kil led well & pooh w/ DST tool. Re-ran DST w/ stimulation valve and DP dry. 39 4O 41 8/26/77 8/27/77 8/28/77 8770'TD 7509'ETD (cmt ret) 13 3/8" csg@2505' 9 5/8" csg. @8769' 8770'TD 7509'ETD (cmt ret) 13 3/8" csg @2505' 9 5/8" csg. @8769' 8770'TD 7509'ETD (cmt ret) 13 3/8" csg @2505' 9 5/8" csg. @8769' Finished RIH w/ 9 5/8" Baker retrievamatic and stimulation valve on dry 5" DP and set pkr @6260'. Pressure DP w/ 1000 psi gas pressure from #41-18. Opened stimulation valve and bled off gas pressure. Flowed rathole mud to surface in 2 hrs and tested all Beluga interval #2 perfs from 6344' to 7264' at 2.9 MMCFPD rate w/ 23 BWPH. Ran GO Int. W.L. spinner and temp survey while flowing well at 3.25 to 3.4 MMCFPD rate w/ 24 BWPH. Killed well w/ W.O. fluid and circulated hole clean. Lost 80 bbls fluid to formation. Pooh. Ran 9 5/8" Baker retrievamatic and stimulation valve on dry 5" DP and set pkr @6680'. Pressured DP w/ ll50 psi gas pressure from #41-18. Opened stimul'ation valve and bled off gas pressure. Flow tested lower Beluga interval #2 perfs from 6790' TO 7264'. (Upper Beluga interval #2 perfs 6344' TO 6474' isolated) at 4.7 MMCFPD rate w/ 2 BWPH for l0 hrs. Recovered drilling mud and water increased to 13 BWPH. Final test rate 4.9 MMCFPD rate w/ 13 BWPH (suspect water movement behind casing). Killed well w/ W.O. fluid and pooh. Ran Baker 9 5/8" bridge plug on GO Int. incomplete. 42 43 8/29/77 8/30/77 8770'TD 6600'ETD (BP) 9 5/8" csg. @8769' 13 3/8" csg. @2505' 8770'TD 6600'ETD(BP) 9 5/8" csg. @8769' 13 3/8" csg. 02505' Finished running 9 5/8" Baker Bridge plug on GO Int. W.L. and set @6600' to isolate Beluga interval #2 lower perfs 6790' to 7264' 'From Beluga interval #2 upper perfs 6384' to 6474'. Ran 9 5/8" retrievamatic pkr on 5" DP and set @6256' Pumped in upper Beluga interval ~ ' ' =2 perfs 6384 to 6474 @22 cfm & 1700 psi. Squeezed perfs 6384' to 6474' w/ 250 sx. C1 "G" w/ .75% D-31 and 1% CaCl2 and staged cement 3 times in 1 hr after clearing pkr to a final pressure of 2500 psi. Released pkr and could not circ. Pooh and found soft cement in 20 jts of 5" DP. LD DP and washed out cmt. Ran 8 1/2" bit, 9 5/8" csg scraper and 6 DC on 5" DP and drilled out cement from 6261' to 6425' Washed to BP @6600' and circulated hole clean. Pooh. Ran 9 5/8" retrievamatic and stimulation valve on dry 5" DP, incomplete. Finished running 9 5/8" Baker retrievamatic pkr and stimulation valve on dry 5" DP and set pkr @6256' Pressured DP to 1200 psi w/ gas from #41-18. Opened stimulation valve and bled pressure to O. Dry tested Beluga interval #2 upper perfs 6384' to 6474' after squeeze w/ no fluid entry in 3 hrs. Filled DP w/ W.O. fluid. Broke dwn. perfs 6384' to 6474' w/ 2000 psi and pumped in @lO cfm & 1800 psi - held 650 psi w/ pump off. Re-squeezed Beluga interval #2 upper perfs 6384' to 6474' w/ 200 sx. Cl "G" w/ .75% D-31 and 1% CaC12 to a final pressure of 3200 psi. Bled to 2800 psi and held steady. Reversed hole clean and pooh. Ran 8 1/2I' bit, 9 5/8" csg. scraper, and 6 DC on 5" DP and drilled out hard cmt. from 6368' to 6476' Washed to ret. @6600' and circ. hole clean. Pooh. Ran 9 5/8" Baker retrievamatic pkr and stimulation valve on dry 5" DP and set pkr @6256'. Opened valve, surged and dry tested Beluga interval #2 upper perfs 6384' to 6474' w/ no entry in 1 l/2 hrs. Filled DP and circ. hole clean. Pooh. 44 8/31/77 8770'TD 750,] 'ETD (junk on cmt. ret) 9 5/8" csg, [a8769' 13 3/8" csg. @2505' Finished pooh w/ pkr. Ran 8 1/2" bit, 9 5/8" csg. scraper and 6 DC on 5" DP and drilled out cmt. ret. @6600', Pushed and washed ret. to 7360' w/ no cmt. across perfs 6790' to 7264' Washed and reamed from 7360' to 7502' and circ, out large amount of fine formation sand. Circ. hole clean and pooh. Ran 9 5/8" retrievamatic and stimulation valve on dry 5" DP and set pkr @6300'. Opened stimulation valve and tested Beluga interval #2 lower perfs 6790' to 7264' for 6 1/2 hrs @ max rate of 1.25 MMCFPD and unloading rathole water, Oil and Gas I ;~on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 August 15, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 -_ 1 .NO" f 3 - i ...... 3 GEOL DRAFT SEC C(~NFER: RE' TBS A-32 TBS A-20 ORM "-~'ELD Dear Mr. Hamilton' Enclosed for your information are two (2) copies of the Monthly Report for the above captioned projects. Sincerely yours, FJim.~R. Callender ~ ..,.~. , sm cc' Marathon Oil Co. USGS Harry Lee SUBMIT IN DUPLICATE For m'qqo. P-4 R'EV. 3- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER (: ERA I,ONS WELL WELL OTHER 2. NAME OF OPERATOR Ati6.r ~ 5 ~;2t1~"~'~//;' Un,on 0il Co. of California 3. ADDRESS OF OPERATOR P. O. Box 6247 D!vl~ion of ~il arid Gas 4. LOCATION OF WELL 804'S & 675'W of the NE Corner, Section 18, T4N, RllW, S.M. KU 41-18 drilling pad $. APl NUMERICAL CODE 50-133-20304 6. LEASE DESIGNATION AND SERIAL NO. ADL 22330 7. IF 1NDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kenai Beluga Unit 9. WELL NO. KBU 13-8 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC. T. R. M. (BOTTOM HOLE Se°~'.EC§V.E'T4N, R11 W, S.M. 12. PERMIT NO. 77-29 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 7/18/77 20" cond. @114 'RKB 7/19/77 169'TD 20" cond. @114' Staked surface location on 41-18 drill pad approximately 804'S & 675'W of NE Corner of Section 18, T4N, RllW, S.M. 6/28/77 Moved const, equip, to K.G.F. 6/29/77 Started road construction and pad preparation for location site. 7/10/77 Completed site construction & road repairs, moved out const, equip. 7/11/77 Started turnkey rig move and rig up operations. 7/17/77 Completed turnkey rig move & rig up operations. Brinkerhoff Rig #59 went on company time - operating rate @7:00 p.m. 7/17/77 7/18/77 Rigged up Delmag D-22 drive hammer & drove 20" - 104#/ft. drive conductor to refusal @200 B.P.F. @ 114' below RKB or 95' below ground level. Cut off 20" conductor 40" below ground level & installed O.C.T. 20" SOW X 20" 2M-MSP starting head. Installed 20" riser & 20" hydril - mixing spud mud. (Footage 169') Completed installing 20" riser & hydril. Mixed spud mud. Picked up 17 1/2" bit & spudded well KBU 13-8 at 4:00 a.m. 7/19/77. Cleaned out 20" conductor to 114'. Drlg 17 1/2" hole to 130' Encountered sloughing gravel. Raised funnel viscoity to ~00. Drlg 17 1/2" hole to 138'. Lost returns- mixed lost circulation mater~,al Drlg to 147'. Total mud lost - 160 bbls. Pulled up to 20 s~oe at 114'. Increased funnel vis. to 250 & mixed 200 bbls of mud w/ lost circ. material. Drlg 17 1/2" hole from 147' to 169'. Mud loss minimal. 7/20/77 518'TD 20" cond. (Footage 349'). Cont. drlg 17 1/2" hole from 169' to 195' in gravel and boulder bed. Maintained mud vis 250-300 SEC/QT & lost 14. I hereby c~r~ha~e fo~?Tg~ is true SIGNED IlilJ.~,C?Z ~'~ff.~ ~' ~.~.~ TITLE Di ce nvl g Cl,13q' DATE 811 5/77 NOTE--Report on tlis form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. @114' circ. material in mud. Drlg sand, silt & clay from 195' to 394'. Maintained mud as above, mud loss minimal. Survey 394' 1/4 deg N7W. Pooh for dyna drill Re-ran bit #1 17 1/2" on dyna drill BHA #2 & oriented at KOP of 394'. Dyna drill & survey from 394' to 518'. No major mud loss. Reduced mud vis to 100 SEC/QT. 7/21/77 7/22/77 7/23/77 7/24/77 937'TD 20" cond. @114' 1852 TD 20" cond. @ll4 2508 TD 20" cond. @ll4 2508 TD 20" cond. @114 13 3/8" csg. @2505' (Footage 419'). Cont. dyna drilling & surveying 17 1/2" hole from 518' to 695'. Pooh & ran angle bldg. BHA #3. Drilled & surveyed 17 1/2" hole from 695' to 937'. (Footage 915'). Drlg from 937' to 1852. Footage 656'). Drlg from 1852' to 2508'. Circulated hole for casing and made short trip to 300'. Circulated for casing &.pooh with bit. Running 13 3/8" casing. (Footage 0') Ran and landed 13 3/8" 61# K-55 csg. @2505' w/ Dowell stab in float collar @2460'. Ran cementing tool on 5" DP and stung into float collar. Circulated hole clean with rig pump. Cemented w/ 1200 sx. Class "G" containing 2 1/2% prehydrated gel in mixing water mixed @98 lbs/cu.ft, followed by 200 sx. C1 "G" neat mixed @ 114 lbs/cu.ft. Displaced cement to float collar and had good cement returns to surface. Pooh w/ DP. Cut off 13 3/8" csg. and installed OCT 20" 2000 X 13 3/8" 5000 psi type TC csg. spool. Nippled up BOPE. 7/25/77 7/26/77 7/27/77 2508'TD (Footage 0'). Finished nippling up 12" 3000 psi BOPE, choke 2460'ETD manifold and kill lines. Attempted to pressure test and valves (flOat collar) failed in choke manifold an rig pump manifold. 13 3/8" csg. @25051 2508'TD (Footage 0'). Finished repairing valves in choke manifold and 2460'ETD pump manifold. Tested all BOPE, choke manifold, kill lines, pump (float collar) manifold, Kelly, Kelly cocks, and surface mud lines to 3000 psi. 13 3/8" csg. Tested blind rams and 13 3/8" csg. to 2500 psi. Test completed @2505' at 9:00 p.m. Changed out blade sleeves on LOR stabilizers. 2977'TD 13 3/8" csg. @2505' (Footage 469'). Completed picking up BHA #6 & 12 1/4" bit #3. TIH - started taking weight on DP @1720'. Circ. btms up. Mud severely gelled & loaded w/ solids. Circ. & cond. mud - stage DP in hole - circ. out 3 times to top cmt. @2438'. Tested 13 3/8" casing to 2600 psi - o.k. Drill cmt., F.C. @2460' & cmt. to 2478'. Retested 13 3/8" casing to 2600 psi - o.k. Drilled cmt. & float shoe @2505'. C.O. rathole to 2508' & drilled to 2510'. Tested 13 3/8" casing seat and formation to .65 psi/ft, grad - held o.k. Directionally drilled & surveyed 12 1/4" hole from 2510' to 2852'. Pooh. Packed tandem BHA #7 to stop angle build. Re-ran 12 1/4" bit #3. Drilled & surveyed 12 1/4" hole from 2852' to 2977'. 10 7/28/77 3457'TO (Footage 480'). Orlg & surveyed from 2977' to 30091 w/ 12 1/4" 13 3/8" csg. bit #3 and tandem locked BHA #7. Angle increasing more than @2505' desired. Pooh to change BHA. Re-ran bit #3 on BHA #8 (under gauge near bit tandem assy). Orlg & survey to 33231. Pooh. Ran 12 1/4" bit #4 on OD BHA #9, oriented dyna drill for maximum right hand turn w/ eye steering tool. Oyna drilled & surveyed from 3323' to 34571. 11 7/29/77 3810lTO (Footage 3531). Ran 12 1/4" bit #3 on dyna drill BHA #9 to TO @3457 - Oriented dyna drill w/ steering tool for maximum right 13 3/8" hand turn. Oyna drilled to 34871. Pooh. Re-ran Bit #3 and csg. @ on BHA #10 - reamed dyna drill run and drilled 12 1/4" hole to 2505' 3502'. Plugged jet in bit. Pooh. Unplugged jet. Re-ran 12 1/4" bit #3 on BHA #11 and drilled to 3810'. 12 7/30/77 4625' (Footage 815'). Drilled & surveyed from 3810' to 39741. Pooh 13 3/8" Ran 12 1/4" bit #4 on BHA #12 to drop angle. Orlg 12 1/4" hole @2505' to 46251. 13 7/31/77 5629'TO (Footage 10041). Orlg 12 1/4" hole wi bit #4 and BHA #12 to 13 3/8" 51 86 I. Pooh for bit change. Orlg wi bit #5 on BHA #12 csg. @ 51861 to 56291. 25051 Union Oil Company .?,alifornia unl July 25, 1977 Dear Mr. Smith- Mr. Rodney Smith U.S. Dept. of Interior Geological Survey 800 "A" Street Suite 109 Anchorage, AK 99501 Enclosed for your information is the weekly report for Well KBU 13-8, KENAI GAS FIELD. Attachment sm cc' State of A1 aska Sincerely yours, q~im ~. Callender 'i's-t~ Drlg. Supt. Division of Oil & Gas C~ Marathon Oil Co. Harry Lee Form approved. Budget Bureau No. 42-R356.5. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LAND OFFICE .............. ,.~E .u.,~E. A02gl ~2 .............. ---Eg-O---1-3:--g ............. UHIT ........................................... LESSEE'S MONTHLY REPORT OF OPERATIONS A State ........ Alaska .............. Co~ty Field .... _K__e__n__a__i____G__a__s___-F-_!-e--1--d-- ............................... The followinE is a correct report of operatior~s and prod~ctio~ (incl~dir~ drillin~ and prod~cin~ wells) for the ~~ of .... .J__u_!y__]_8_-_2_4 .................. ,19__7_Y__, ............................................................................ e~t's address P 0 B_Q~ ~2.~Z ~lff ......... : ..... . ......................................... Company._~qn$gn~J~--Co---q~---Calif ............. _.:_: ........................... ............ :_, ...... ............ Pl~one ...................... 22__6__-_Z6_0_0 ............................................ .4Eent' s title~.._'D_ia.t .... Dr_19 .... Sap_t .................... GALLONS OF BARRELS Og REMARKS SEC.~,~ oFAND~ r~wp. RANGE WELLNo. Pao~oc~-vD~es BARRELS OF OIL ORAVITY Cu.(in thousands)FT' oF GAS RECOVERED(~ASOLINE none,WATERso state)(If (Ifdatedrilling.and reaUltcontentdepth;ofifofte~tshutgas)ford°Wn'gazolineCaUse; .. 18/77 20 cord· S",aked surface lo:ation on ~1-18 drill pad a~proximately 804'S @1 4'R~B & 675'W of IE Cor~er of Sec':ion 18, T4N, Rll 4, S.M. 6,t28/77 Mo~ed co~st, equip to K.G.F. 6z29/77 St/rted road const"uction and pad p-eparation for lo<.ation site. 7.~10/77 Cor~pleted site con ;tructi or & road ~epairs, moved out co~st. ~quip. 7/11/77 Sti.rted turnkey ri~ move ard rig up: operations. ~,,~?, 7/17/77 Co~plet~d turnkey rig move & rig up operations· ill !i'!, '"~ ~ ~*) Br~ nker~off Rig #5~ went or company time - operating ~ ra':e @7'00 p.m. 7/!7/77 ~.~ 104# ~,,~,~..~r~~ 7~18/77 Ri Iged ~P Delmag D~22 drive hammer ~ drove 20" - ~ ~ ~" dr ve conductor to refusal @200 B P F @ 114' below R ci clx,\ '?.,~'~ ~,.v.~, c_;~;~,,s'.:-'. ?~tio:~ o' 95' below grou id level Cut off 20" conductor 40 .... be ow g~ound level & insta'led O.C.T. 20" SOW X 20" Ar,~or:~c~ 2M-MSP ,~tarting he~d. Insl;alled 20" riser & 20" hyiril - mixing sp~d mud. t19/77 169'TD (Footage 16)') C(.mpleted in;tailing 20" riser & hydri~ Mixer 20" co,id, s)ud mud. ~icke~ up 17 1/2" bit & ;pudded ~ell KBU 1 '-8 at 4' @114' a.m. 7/19/711. Cleaned out 20" cond~tctor to 114'. Drlg 17 1/2 ~ole to 130 . Er~countered sloughin!t gravel. Raised funnel Niscoity to 200. Drlg 17 1~2" hole. to 138'. Lost returns - n 'lost circulation material. Drlg to 147'. lotal mud lost - 1( t~bls. Pull_:d up to 20" shce at 114 . Increased funnel vis. i 250 & mixed 200 t bls of muc w/ lost circ. material. Drlg 17 1 ~ole from 1~7' t(I 169'. Mkd loss m'nimal. /20/77 51~8'TD iFootage 349'). Cont. drlg 17 1/2" hole frc,m 169' to 195' in 2C" co~d. travel and bould~,~r bed. Maintained mud vis 250-300 SEC/QT & ' @114' circ. material i~ mud. Drlg sand, ;ilt & clay from 195' to 3! I, aintained mud a'.; above, mud loss m nimal. Survey 394' 1/4.d~ 17W. Pooh for d,na drill 6e-ran bi~ #1 17 i/2" on dyna drill 7/1 : ,. /ft.i RKB 7/1 O0 xe( 6O to /2" lost ! · · NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoTw.--Report on this for~n is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Folqn 9-329 (January 1950) 8 9 2- 5 56 u.s. GOVERNMENT PRINTING OIrFICE: ~Jf~4~729-784 7/21/77 7/22/77 7/23/77 7/24/77 937 'TD 20" cond. @114' 1852 'TD 20" cond. @ll4' 2508'TD 20" cond. @ll4' 2508'TD 20" cond. @ll4' 13 3/8" csg. @2505' BHA #2 & oriented at KOP of 394'. Dyna drill & survey from 394' to 518'. No major mud loss. Reduced mud vis to 100 SEC/QT. (Footage 419'). Cont. dyna drilling & surveying 17 1/2" hole from 518' to 695'. Pooh & ran angle bldg. BHA #3. Drilled & surveyed 17 1/2" hole from 695' to 937'. (Footage 915'). Drlg from 937' to 1852. Footage 656'). Drlg from 1852' to 2508'. Circulated hole for casing and made short trip to 300'. Circulated for casing & pooh with bit. Running 13 3/8" casing. (Footage 0') Ran and landed 13 3/8" 61# K-55 csg. @2505' w/ 'Dowell stab in float collar @2460'. Ran cementing tool on 5" DP and stung into float collar. Circulated hole clean with rig pump. Cemented w/ 1200 sx. Class "G" containing 2 1/2% prehydrated gel in mixing water mixed @98 lbs/cu.ft, followed by 200 sx. C1 "G" neat mixed @ 114 lbs/cu.ft. Displaced cement to float collar and had good cement returns to surface. Pooh w/ DP. Cut off 13 3/8" csg. and installed OCT 20" 2000 X 13 3/8" 5000 psi type TC csg. spool. Nippled up BOPE. Union Oil and Gas E ~ion: Western Region Robert T. Anderson District Land Manager Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 Telex' 90-25188 union J~ne 27, 1977 State of Alaska Department of Natural Resources Division of Oil and Gas Conservati~ 3001 Porcupine Drive Anchorage, Alaska 99501 3 GEOL ! .... REV -'-~i~^FT '] CONFER: Attention: Mr. Hoyle Hamilton KENAI SOLDOTNA AREA State of Alaska U.S.G.S. Approved Application for Permit to Drill KBU 13-8 (ADL-22230, A-028142) Gentlemen: Enclosed for your files is a copy of the U.S.G.S. approved application for permit to drill the above-referenced well and a copy of the U.S.G.S. transmittal letter for your files. Very truly yours, Wayne Rodges Landman vs Enclosures UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY 800 'fA" Street, Suite 109 Anchorage, Alaska 99501 June 23, 1977 Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 Re: Kenai 13-8, APD Attention: Robert T. Anderson Dear ~,~. Anderson: Attached is an approved copy of your Application for Permit to Drill the KBU 13-8. The surface.location is on Lease ADL 22330 and the bottom hole is on lease Anchorage 028142. This approval is subject to the requirements set forth in NTL-6 and the attached CONDITIONS OF APPROVAL. On this ~£.~_~.~_.u~_~_r_.>~, this office will not require that you comply vdth item 7 of the CONDITIONS OF APPROVAL. By copy of this letter, we are notifying the Alaska Oil and Gas Conservation Committee of our approval of thi~ APD. If you have any questions or need any additional information that we may furnish, please let us know. / / ,'. . , ..... Rodney ,A. Smith Oil & Gas Supervisor Alaska Area Encl. WELL NO. CONDITIONS OF APPROVAL Union Oil Comps_ny LOO~ITION KBU 13-8 Surface - ADL 22330 Surface - NE NE Sec. 18-T4N-RllE ~ O-a ~ Bottom Hole - A-028142 LEASE NO. B ~,%DBL_t[O -~'~-Sec~_ftg=/14~-thllW All lease and/or unit operations are to be conducted in such a manner that full compliance is made with the lease terms and the operating regulations, 30 CFR 221. 1]~e following items are emphasized: · 1. There shall be no material deviation from the proposed drilling and/or work- over program as approved. Safe drilling and operating practices must be observed in regard to e'quipment and personnel l~,ne use and frequent testing of blowout prevention equipment is mandatory. All wells, whether drilling, producing, suspended' or abandoned, shall be identified in accordance with 30 CFR 221.22. 2. Ail shows of fresh water and minerals will be reported and protected. Ail oil and gas shows will be adeeUately tested for co~mnercial possibilities, reported and protected. 3. No location will be made or moved, no well will be plugged and no drilling or workover equipment will be remo%ed from a well to be placed in a suspended status without prior approval of this office' 4. '~4ell Completion or Recompletion Report and Log" (Form 9-330) will be submitted not later than 15 days after completion of the well or after completion of oper- ations being performed, in accordance with 30 CFR 221.59. Two copies of al__l logs run, core descriptions, core analyses,, well test data, geologic summaries including formation tops and sample descriptions, and all other surveys or data obtained and compiled d~ring the drilling, workover and/or completion operations will be filed with Form 9-330. SamPles (cuttings, fluid and/or gas) will be submitted only when requested'by this office. 5. "Sundry Notices and Reports 'on Wells" (Form 9-331) will be filed for all changes of plans and other operations in accordance with 30 CFR 221.58. Emergency approval may be obtained verbally, but such approval does not waive the written report requirement. Co~nencement of operations wili-'be reported promptly by Sundry Notice. 6. During drilling operations, weekly reports surmmarizing the operations shall be timely filed in duplicate with the Area Oil and Gas Supervisor. If productive, this report will be converted to a monthly basis (Form 9-329) and filed prior to the 10th of the following month. (See section 221.60 and 221.65 of Federal /'~k Oil and Gas Operations Regulations.) :. !7. i Representative cuts (washed) of all ditch samples and cores shall be collected for U. S. CeologicaI Survey. (Sample sacks will be furnished upon request.) Ship samples to Geologist in Charge, USGS, 310 First Avenue, Fairbanks, Alaska, 99701 with instruction to convert to Government Bill of Lading on arrival. MsilinE Address Area Oil and Gas Supervisor U.S. Gaological Survey P.O. Box 259 Anchorage, Alaska 99510 Office Address 800 "A" Street Room 205 Telephones: Office: 278-3571 Night: 333.-4630 337-26119 333-2754 ~prT~..9.~:LC SUBMIT I'H T~-~P_-L~T~*7 Form appror~. (Other ~r muon~ on '~'~) ...... ~ NITED STATES ~,-~ ,~tc~ o~ r~ DEPARTMENT OF THE INTERIOR O~L & OAS SL~",~ ' GEOLOGICAL SURVEY tl ~ ~ ~ ,~g 2233 AppLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG ~C~ u '~u~x~:'x~:~o~.~,,,,,~,.,,,~ 1~1. TIt'PE OF WORK ·DRILL b. Tt,'PE OF WELL O,L [~ CAS ,~ WEL~ DEEPEN []] o~rIER ZON~ OPERATOR Union Oil Company of California '909 West Ninth Avenue, AnchoPage, Alaska 99502 LOCATION 03* WELL (Report locat.loa clearly and in accordance with any State requirements.*) At ~urface 780' S a 700'W of the NE Corner; Section 18, T4N, · RllW, S.M. KU 41-18 drilling pad ~trrOpO~dprod.~-one Beluqa sands - 1200'N & 420'E of the SW Corner, S_e~:Uon 8, T4N, RTIW, S,M, ,, DI/~TANCi/I I~ $IILE~ AND DIRECTION I~'RO~I NEAREST TO~N OR P0~T OFFICE~ 6 air miles south of Ke~ai " SURVEy ~sKJ~enai Beluga Unit ~,1. i$~C., T.~ R., Bf., O,~ , AND EIURVI~' OR AREA 'Sec. 8:T4N,R[IW,S2M- A-0281~2 Z2.:.CO~;NTr OR ~'~r~aat. ~s. . 1~. DISTANCE FROM PROPOSIiID~' 16. NO. OF ACRES IN LEAS-~- 17. NO. 0b' ACRE3 . LOCATION TO NEAREST ', TO THIS ~o~z o~ ~.~s~ ~x~,~r. 2000 ft. 2560 320 '. ' ' ' : '" (AI~o to nearest drlg. unit line, If nay) '' - ":" 18. DISTANCE FROM. PROPOSE~ LOCATION* 19. PROPOSED DEPTH 20. ROTARY OR CABL~ ~OOL~ TO NEAREST WELL, DRILLING, COMPLETED, " ' o~ ~-~ ro~ o~ ~,, ~, ~. 630¢'ft. 8200' TMD, 7425TVD RotarY .. - 21. N~AT1ONS (Show ~he~e= DF, ~T, CE, e~.) ! 22. a~aox. ~ATn WOaN W~L~ i - ' ''July l, 1977': ~3. PROPOSED C~8ING ~ND ~EM~NT~'G P~O~R~5~ ' . .f '~ . ~IZE OP HOLE ~IZB Ob' CA~ING ~ETTtNG DEPTH QUANTITI' OW CEMENT 17____1]_2" '12 1/4" 20" 13 3/g" 9 5/8" See page 2 ~PFEIGHT I"ER FOOT ! 9 -" 147 ' - . Dri yen 100' 75Z10' 8200' 1,7.36 cu-ft- As determined from-logs" . , .. , .. .,, · ~ _ . ._ .... -.. .. ., ,. . ,, · .. · · .... .:. · . · · · · IH ABOVE ~PACE DESCRIBE PROPOMED PROGRA~I: If proposal is to deepen or plug back, give data on present productive zon~ and I~ropose(l new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations awl measured and true vertical depths. (lire blowout prerenter program, if any. -- (This space for Federal or State o~ce use) / / / , / / / , .' ff .. District Land I,la[~a~q~r , - ,.,'r,: __6~3!,77 APPROVAL DATE · *See Instructions On Reverse Side U. S. Dept. of Interior Geological Survey Permit to Drill Page 2 June 3, 1977 PLAN-OF PROCEDURE- · 3, Be Drive 20" conductor to 100'+. Install BOPE assembly #1. Drill 17 1/2" vertical hole to +1000'. Kick off well and drill 17 1/2" directional hole to 2500'. Run and cmt. 13 3/8" csg. @2500'. Install BOPE assembly Drill 12 1/4" directional hole to 8200' (core upper Beluga formation as required,) Log wel 1. ' Run and cmt. 9 5/8" csg Complete well as gas producer as determined from logs. Estimated OPer. atin. g_ Time' Drilling Time .~ompl etion Time Total Time Twenty Two (22) Days Fourteen (14) Days Thirty Six (.36) Days CASING DESIGN 13 3/8" Casing- Interval Fqo_t a.q=_e_e Description Wt. Acc. S.F.T. S.F.C. O-2500'TMD 0-2387 'TVD 08200' 2500' 61#K-55 Butt. 152,500 8200' 9 5/8II Casin_g_ 47#N-80 Butt. 385,400 152,500 6.3 1.29 385,400 2.8 1.28 C 1 .o Z1EC.EI VED OFFICE OF THE & GAS SUPERVISOR 'JUtJ 0 8 1977 · ' ' L SURVEY 'ANCHORAGE, ALASKA (___6 e £! II~ D /?,41;$ /IE CEI VED OFFICE OF OIL & GAS SUP~.RvlSOR JUl',] 0 8 1977 · CONS~RYATION DIVISION U.S. GEOLO~L,L.~.L SURVEY ^NCHORAG[, · 64 lE VA L V~ NOTE' ALL CHa,,','GES MUST APPROVAL BY THE O!STRtCT , /. ._- .2'::-: : · o · o o ! · ON tATHON HP 4 5 U- M KDU 4 RD ,..~' , ~....~'- g TMD 6.530 TMD I0,810 -00593 A -028142 RATHON UNION .... · 13 E U / . · t H P KU - 43-7 TMD 5707 8 KBU 13-8 Q PROPOSED B.H.L. // _+8200' TMD / .I- 74.25' TV D ! /o,~--.- TA RG E T B TARGET A--*~/ T/BELUGA FM. / ~ 54.75' MD T/C-I SAND ! U M 5200'MD / - +-4850' VD / ...~K U h - I 4650' VD / F,o-r~14X_8) // J F", TMO 14,721 /I,.<' ! ../,-' ~4',- ,~ - MARATHON H P 17 .~KU 44-18 .-. }MO 6020 \ KU 41- 19 TM 0 .5653 ADL - 00594 RI2'~ T : ADL - 22330 : · · · · RilW oIt CON: Ah 0 I000 2000 4000 2O U~M -~KU 14-4 TNID 5125 UNION MARATHON · UNIQN .......... MAR~,THON · · · I~ · · · · ADL-O0460 21 t = 2 O' '! MAR 30.-77~ [ ~ HP .~.~ ~ i \~ ~ ~-~ Alaska District OFFICE OF i -' GAS FI F_.L.D tU['t 0 ,S ~'" WELL LOCATION EXVATICx: ~'."S~ON ;~o~e ..... ~.,.~=~ K.B.U. 13- 8 A-028047 F!LE. 'i? Memorandum Union Oil Company of California June 17, 1977 iIECEIVED OFFICE OF THE & GAS SUPff2VISOR TO: FROM- . · .. . . · Wayne Rodges %/< . 'JUI'J 2 'i 1977 CONSERVATION DIVISION U.S. GEOLOGICAL SU2VEy KENAI BELUGA UNIT #13-8 - 7. . In :.reply to your request for additional and more technical information as required by the U.S.G.S. for approval of the drilling permits, the following is submitted:. ":. .. " · ~ . NTL ' (6) ': Estimated top's of geologic markers Sterling Pool No. 3 · Beluga . .'. -/ Tyonek 3658'TVD 4850'TVD 7218'TVD (7) Anticipated gas bearing formations (wa[er or oil bearing formations not expected). Ste'rling Pool No. 3 Sterling Pool No. 4 ..... Sterling Pool No. 5.1 Sterling Pool No. 5.2 Sterling Pool No. 6 Beluga : ,. 3658'TVD 3898'TVD 4028'TVD 4558'-TVD 4650'TVD .4850'TVD . (10) S~hematic of 15OPE showing size and pressure , , ?r3. rating. See attached schematics ~1 #2 ~ , .. · Ail BOPE to be tested to 80% of the ~ninhnum internal yield pressure of casing installed on except the Hydril'which ,:viii be tested to 70% of ram preventer test Pressure. Tests to occur upon instal!at,on and · ' at 7 day intervals thereafter. (11) The type and characteristics of circulating mediums. It is proposed to drill the xvell from 100'-TD with a fresh water, low solids, non-dispersed, polymer type Wayne Rodges KBU #13-8 June 17, 1977 mud. Typical characteristics of such a mud to be used in this area would be: , Weight - 70-808/ft. Viscosity - 40-60 Sec/t000 cc Fluid Loss - 10-15 c'c/30 min. Salt - 1500 ppm Solids - 10% Volumes of mud will be the minimum amount required to circulate ~he hole plus a safe operating surface volume and should not exceed 2000 barrels a.t any time' Mud required will be a bentonite gel, polymer chemical · as selected, soda ash, and barite as needed for weight. (13) Abnormal temperatures or pressures, H2S, or any such potential hazards are not expected to be encountered. JRC/MTD/sk Attachments 23, ]'977 Pe.~-~t ~. 77-29 J. R. Call~ District Drih"u~ SuperPaint ~ 6~47 ~~ag~, ~ 99502 Enclosed is ~ approved ~lication for pera~t to drill the above refer~ w~_!l at a Iocatic~ ~ ~T/~n 8, Town~hip 4LH, Rankle llW, SM. Core chips are re~red. ~11 ~~ ar~ a mud log are not r~quired. A directi~ ~ is requL~ed. Marry rivers ~ ~ and their drainage ~ have been classified e~ i~portant for ~ sp~n/ng or migraticn of anadr(xmnus fish. Operations in ~ ~ are subj~ to D~ 16.50.870 and the regula~ ~gat~d ther~~ (Title 5, Alaska Adm/nistrative Code). Prior to ~ing operations ~ ~ ~ cx~~ by ~ Habitat Coordinator's office, Depart- ~nt of Fi~ ~ ~. Pollution of andy waters of the State L~ prohibite~1 by AS 46, Cha~ 03, Article 7 ~ ~ re.rictus ~pr~lgated ~3~eunder (Title 18, Alask~ Af~nistrative Cc~e, Chap~ 70) and by ~ Federal I~ter Pollution C~ntrol ~, as amer~d. Prior to ~ing operations you may be conta~ by a repr~tative of ~ D~pa~-~m~ t of Envi~tal Conservation. ~suant to AS 3~.40, Local F/re ~ Sta~ Leases, the Alaska Department of ~ is be~ notified of ~ issuance of this permit to drill. TD aid us in ~-uling fiel~ work, we would a~Tpreciate ~ur notifying this office within 48 ~ after t/~ ~I is spud~!. ~ ~m~ld also like to be notified so that a repres~%tative of t~'~ Division may be present to ~<itness ~sting of b!c~ut p _r~zenter ~.~~t before s~rface casing, shoe is drilled. J. Ro ~allendar ~ Betuga Unft -2- May 23, 1977 In ~ ~ of ~ic~ or abandonment please give this office adequate advance notificati(a% so that ~ may ha~e a .witness present. Very truly yours, Department of Fish and ~, Habitat Sectic~ w/o encl. Department of Env~tal Cc~serva~ w/o encl. D~m~t of ~, Superior, Labor Law C~plian~ Divisic~ w/o encl. form I0-- 401 RLr~. I-I--TI TYPE OF WIILL SUBMIT IN 'CHI (Othermstr'uct/oh, on STATE OF ALASKA OIL AND GAS CONSERVATION ,COMMITTEE' reverse side~ PERMIT TO DRILL OR DEEP£N DRILL J~]X DEEPEN [] WI:LL WELL 0TH~!~ ZO N Ii; ZONE 2.NAME OF OPEt:L~,TOR UnJ_on._0il Company:of Cal ifarnia . 3.ADDRES~ OM' OPF.~ATOR . 909 West Ninth Avon. ua: Anchorage..A!aska.99502.. 4. LOCATION OF WELL Atsurfa~e 780'S & 700'W of the NE Corner, Section 18, T4N, 13. API No. 50-133-20304 LEASE DICSIGNATION AND SEI~IA~ NO. ADL-22530 7. IF INDIAN. A. LiX)TrI:,-~ OR TI:~IIE NA.1NIE At proposedprod, zone Beluga sands - 200'N 20' E of the S.W. Corner, .Section 8, ,T4~, RllW, S.M DISTANCE IN MILES AND DIRECTION FROM NEAF{EST TOWN OR POST OFFICE' air miles south of Kenai 8. UNIT FARM Oil LEASE NAME Kenai Beluga_Un_it , , 9. WELL NO. ~- .. 10. FIELD AND POOL. OR %VILDCAT Kenai._Gas Fi eld ..... I1. SEC., T.. R.. M.. CBO'FTOM HOLE OELIECTIVE~ Section 8- T4N , RI IW, S.M. A-028142 14. BOND INFOI~MATION: TYPE Statewide Sur~ty..d/or ~o.United Pacific .I, nsurance 15. DIsTANcE FROM PROPOSED* ii6. NO. OF A~iqES iN fi. EASE LOCATION TO NEAREST ! ' PROPERTY OR LEASE LINE, ~. (A~o to ne.,-~t ~=~...it. i~ ..~> 2000 ~t. ~ ~. 2560 18. DISTANCE FROM PROPOSED LOCA~ON' Fi'~[ pROPOSTM D~ o~ ~=,~ ro~. m. 8200 6,300 17425 21. ELEVATIONS (Show whether DF. RT, CH, etc.) 2.'1. PROPOSED CASING AND CEMENTING PROGRA~M 17. NO. ACRES ASS/GN'ED TO THiS WELL 320, 20. ROTARY OR CABLE TOOLS Rotary ?-2. APPROX, DATE WORK WILL STAH'r* . _Jul_v_ l, 1977 .. SIZE OF HOLE SIZE OF CASINO WEIGHT PER FOOT GRADs sls'r'I'ZNG DEpTH quantity of cement 20" 20'.' 94#/ft. H.40 10O' Dci ven. 17 1/2" ]3 3,o'' .. .o '6t#/ft .... K-55 25ON' 1736 .au.ft. l 2 1/4" q 6/8" ......... a7# · ,. N-80 ri?an, .... /lq Hmfm_rminad fram lanq. ....... See page 2 IN ABOVE SPAC!g DESC"RIB~ I~ROPOSED pROiJR.~'vl: If ~1 ts to dee~n give ~ on present p~u~ive zo~ and pro~ new preclusive zone..If ~1 iS ~ drill or a~n a~onaliy, give ~rt~ent ~' on s~bsu~a~ ~t~ ~d meax~d mad ~ue 've~tcal dept, Give-blo~u[ preventer7 p~gram. 24. I hereby certify that the .EpregoLng is T~u,~ e an~} Correct :....~. ,:_~ ~ ,.....:.:~-, ~- ~ . ~ .,~ ~ Dist. Drl q. (Thi~ space for S~te o[fice u~) CONDI~ON$ OF ~P~V~, IF ANY: SAMPLm AND CORE CHIPS REqUn~ $~[ID LO C ~ ,, , . ~ Y~ DX~O~AL SUaVEV ~v~ D NO OTHE~ REQU~'~: A.P.I, 1TLLM. IgHICAL COD~ · Supt. ~i~ 5/16/77 50-133-20304 APFROVA_L DAT~ May_ 23,_ 19.77 May 23, 1977 Permit to Drill of Deepen Page 2 May 16, 1977 PLAN OF PROCEDURE: 3~ . Drive .20" conductor to 100'+. Install BOPE assembly #1. Drill 17 1/2" vertical hole to +1000'. Kick off well and drill 17 1/2" directional hole to 2500'. Run and cmt. 13 3/8" csg. @2500'. Install BOPE assembly #2. Drill 12 1/4" directional hole to 8200' (core upper Beluga formation as required.). Log wel 1. Run and cmt. 9 5/8" csg. Complete well as gas producer as determined from logs. Estimated Operating Time: Drilling Time Completion Time Total Time Twenty Two (22) Days Fourteen (14) Days Thirty Six (36) Days Interval Footage O-2500'TMD 2500' O-2387'TVD Interval Footage 0-8200' 8200' CASING DESIGN 13 3/8" Casing Description 61#K-55 Butt. 9 5/8" Casing Description 47#N-80 Butt. Wt. Acc. Wt. S.F.T. 152,500 152,500 6.3 Wt. Acc. Wt. S.F.T. 385,400 385,400 2.8 S.F.C. 1.29 S.F.C. 1.28 /. ~L I/ID 'hA/,;S · .o ANGLED FILL UP L/NE HYDRIL HYDR,~UL I$ OPEP,~ TED VALVE /. / GJT~ 0,~ GATE VALVE .o 1 GATE VALVE PIPE 1~,4,',/S · NOTE: ALL CHANGES MUST HAVE ~VRITTSN APPROVAL. BY THE DISTRICT DRILLING SUPER!,NTENGE,N T ~... · ~_ ._ .~__. ,. , _ SC~ N on e PO$!T~'/£ · o · J ,I STAND - ARCO . ON ATHON HP -00593 ION RATHON I U-M ~ et ,5 K~ -43 TMO 570 U- M lt4 T3-6A U N I 0 N M D530o M A R A T H (J N 9 ~ KDU- [ ~1 .j.~~~ '' 6 ? 8 ...-~,.-d. T M D 9895 ,U- M z 2 . KU-14-6~:~ ' / ~ TMD 445~ KDU-2 4 T MD 5 540 '~ KDU 4 RD~ A -028142 TMD IO,522 8 _~. U - M ~5 KBU 13-8 KU- -7 /0 PROPOSED B.H.L. TMD:[5707 / ±8200' TMD I~ //_+74.25' TVD /o~----TA RG ET B TARGET A--~"o/ T/BELUGA FM. / ~5475' MD T/C-I SAND / u- M +-.¢850' VD 5ZOO' MD ' / 4650' VD // ._(~KUH 14,oq ,, ]_ ~ TMD ,4,7;~l UNION - MARATHON EU ADL - 00594 24 RI2W 18 H P 17 U-M ,_~KU 44-18 TMD KU 41-19 TMD 565~ · : - ~ ADL-22350 : · · · · · 19 ................................ ' 20 R IIW 0 I000 2000 4000 KENAI union U-M -~KU 14-4 TMD 5125 UNION MARATHON HP Alaska District A- 028047 · · MARATHON · · · EH 16 · · · · · ADL-O0460 GAS FIELD WELL LOCATION K.B.U 13-8 21 AUTHgR SCALE I DATE I"= 2000' MAR.:50,77 IDRAFT'D ] CHEgK,'O FILE N~ _ CHECK LIST FOR NE~I WELL PERMITS 1. Is the permit fee attached 2. Is well to be located in a defined pool ............. 3. Is a registered survey plat attached ................ 4. Is well located proper distance from property line . 5. Is well located proper distance from other wells .......... · 6. Is sufficient undedicated acreage available in this pool 7. Is well to be deviated ....................... 8. Is operator the only affected party ................ 9. Can permit be approved before ten,day wait ............. O. Does operator have a bond in force ................. 1. Is a conservation order needed ................... 12. Is administrative approval needed ................. 13. Is conductor string provided .................... 14 Is enough cement used to circulate on conductor and surface . 15. Will cement tie in surface and intermediate or production strinqs 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... 18. Hill all casing give adequate safety in collapse, tension & burst 19 Does BOPE have sufficient pressure rating - Test to _]~ psig 20. Has DME~.~ approved Plan of Operation ................ Additional Requirements' Company ~'/f~/m m Yes No Remarks Approval Recommended' Geol o.gy- TRM ~.~~ HWK ,, Enqineering: . Revised 11/17/76