The URL can be used to link to this page

Home My WebLink About220-0451. 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: Set Liner, N2 Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,521 feet 5513 & 5820 feet true vertical 5,838 feet ~5520 (WL fish)feet Effective Depth measured 4,650 feet 1636' & 3056'feet true vertical 4,001 feet 1526' & 2636'feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 5.4# / L-80 4,739' MD 1,529' TVD Packers and SSSV (type, measured and true vertical depth)DHL Hydra Pkr; N/A 3,056' MD 2,635' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Chad Helgeson, Operations Engineer 323-295 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 chelgeson@hilcorp.com 907-777-8405 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 0 830 0 110 29 measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-045 50-133-20689-00-00 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: FEEA028142; FEEA028143 Kenai / Sterling 4 Gas Kenai Unit (KU) 42-12 Plugs Junk measured Length Production Liner 4,885' Casing Structural 5,836'6,521' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,778' 8,730psi 2,980psi 6,890psi 10,600psi 1,778' 1,636' Burst Collapse 1,410psi 4,790psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:23 pm, Sep 29, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.09.29 12:18:28 - 08'00' Noel Nocas (4361) Rig Start Date End Date 8/14/23 8/31/23 SITP=0psi, opened well observed fluid level at surface. P/u handling tools and prep rig floor. Spotted and R/u pipe handler, Racked and tallied 2-7/8" EUE workstring. P/u milling BHA and following. 4.5" Tapered Mill, spear ext, 4.5" string mill, 2- 4" boot baskets, Bumper sub, Jars, 2 3" Drill Collors and Acc Jars. BHA=117.36'. Crew preformed bare pipe shut in drill. RIH w/milling BHA p/u 2-7/8" EUE tbg f/117' and tagged @ 4129'md.(jt 127). Set down 5k confirmed tag. PUW=28k SOW=20k. L/d tag joint. C/o handling eq. R/u power swivel and service loops. 08/17/2023 - Thursday PTW and PJSM. Discussed daily activities with AAO crew SITP 0psi, open well confirmed static. R/u and anchored static lines for power swivel. N/u 11"x7" adapter spool and 11" circulating head. P/u joint installed circulating rubber. Established paraments, PUW=26k, SOW=18k, Rot wt 19k. Rev circ 3bpm/850psi, 60rpm. KIH tag and wash/ream f/4129' t/4200' seen light sand return at shakers. Lost full returns @ 4101'. Tried to establish returns both direction no luck. Started pumping long way at 3bpm/60psi with no returns. KIH dressed off perfs and corkscrewed csg at 4203'-4216' seen min torque. Continued RIH f/4216' and tagged 4564'. Tbg plugged off, worked pipe unplugged tbg. Attempt to wash down to 4594' but pickup wt was sticky with overpull and with no returns. Discussed OE decided to come out of the hole. L/d power swivel, POOH L/d wk string f/4594 t/4100' (100' above P3A7 perfs). Secured well and SDFN. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 42-12 50-133-20689-00-00 220-045 08/15/2023 - Tuesday Approved PTW, held PJSM and discussed daily activities. N/d production tree, Installed new Tbg head spool and test 250- 5000psi-held 15mins good test. N/u 7" BOP Stack, R/u work floor handrails and stairs. Finished torqueing up on stack. Installed Kill/Choke lines, lay out and hooked up Kommey hoses to stack. Nitrogen pre charge check on bottles. Had one bottle leaking repaired bladder all good. Function tested bop's, could not get accumulator remote panel to light up, troubleshot issue while testing BOP's, reset remote panel all good after that. M/u 2-7/8" test joint. Performed shell test. Tested BOPE as per Sundry as following: Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi, held and charted test for 5mins low and high. Tested gas detection and performed accumulator drawdown. 1 fail/pass record on remote panel. Witnessed by AOGCC Inspector Adam Earl. L/d testing eq. Pulled BPV well static. Secured well. SDFN. 08/14/2023 - Monday PTW, PTSM, R/D electrical from wellhouse & remove, n/d flow line from tree, smooth pad, lay liner w/felt set Base beam, spot choke house. Spot rig t/ well center, finish spotting eq. Start r/u pits choke house, install gas buster plug in electrical. Stand mast, secure same, scope up mast & secure, install stairs & finish landings, start r/u circ lines. Check well slight blow, R/U pump into well, pump 3 BPM, cought pressure @ 35 bbls pressure up, shut down monitor @ 400psi held, bled off re-pumped same results until hole full. Monitor well one hour static, install BPV. Secure well for night. 08/16/2023 - Wednesday Rig Start Date End Date 8/14/23 8/31/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 42-12 50-133-20689-00-00 220-045 08/19/2023 - Saturday PTW and PJSM ,discussed plan forward Check well Static. R/u circ eq. Pumped 65 bbls down IA and 20bbls down Tbg, monitored on vac. Continued RIH w/2-7/8" EUE liner assembly f/3895' and tagged at 4625'md. R/u head pin and Kelly hose, washed down f/4625'md t/hanger depth at 3bpm/30psi with no returns. M/u the Tbg hanger and 2-7/8" landing Jt. PUW=36k. Washed down and Landed completion w/17k down on hanger. RILDS. MIRU Fox Cementing Eq. PT lines to 1200psi. Held PJSM and discussed pump schedule. Lined up to pump down Tbg returns up IA. Pumped 5bbls freshwater spacer, Mix and pumped 38bbls of 15.3ppg class G slurry at 4bpm/0psi, IA static. Dropped dart and displaced 22bbls began to build lift pressure to max of 300psi. Bumped plug at 27bbls displaced to 630psi held pressure for 2mins, Bleed Tbg back to 0psi and no flowback. Cement in place at 14:09 Yield 1.23 cuft/sk Water 5.6 gallons/Sk Thinking time= 6:27 hr:mins 500psi= 10:29 hr:mins. R/d cementing eq. L/d landing jt and set the BPV. Cleaned and cleared Rig floor, disconnected Kill/Choke lines and accumulator hoses, N/d BOP's N/u Production Tree. Pull BPV set TWC. PT void and tree 250-5000psi.- good test. Secure well and SDFN. 08/20/2023 - Sunday PTW and PJSM, discussed daily activities. Put away koomey hoses, kill/choke lines and circ hoses, Removed doghouse, disconnected electrical. Prep and L/d derrick and moved out carrier, loaded eq on trailers and move to SRF. Picked up containment and finally cleanup around work area. Approved PTW and PJSM, MIRU YJ E-line and crane. M/u tools and stab on well. M/u GR/CCL and 1-11/16" CBL, RIH and set down at 1550', W/t and couldn't fall. POOH Reconfigure tool string, RIH w/GR/CCL and 1-11/16" CBL, tagged at 4406' w/t to 4416' and started observing overpull. POOH, TOC at 3550' M/u 1-11/16' junk basket, RIH and tagged 4416', POOH recovered sample of wet cement. RDMO E-line and crane. Secure well. 08/18/2023- Friday PTW and held PJSM, discussed daily activities. Check well Tbg and IA on slight vac. R/u circ eq. Pumped Tbg and IA volume. Monitored well on vac. POOH f/4100' standing stack 2-7/8" EUE Tbg t/BHA. Pump 1bpm hole fill while tripping. C/o handling eq. L/d milling BHA, Tapered Mill and String Mill had min wear. continuous hole fill at 1bpm. Cleared and cleaned rig floor. C/o handling eq. Tally completion jewelry. continuous hole fill at 1bpm. P/u 2-7/8" EUE Jt with cut mule shoe on bottom, M/u 2-7/8" float collar, RIH 2-7/8" EUE 8rd Tbg f/Derrick Rig Start Date End Date 8/14/23 8/31/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 42-12 50-133-20689-00-00 220-045 Hold tailgate meeting with essential personnel. MIRU Hilcorp hot oil pump truck to IA. PT pump line to gate valve 250/3500 psi. Open IA gate valve. Online down IA. 3.1 bbls away pressure increased to 1000 psi. 1433 hrs start 1500 psi IA MIT as per sundry. Start time 1433 hrs @ 1709 psi. 30 minute end pressure 1683 psi. 26 psi loss over 30 minute test. Bleed back IA pressure test to tank. RIg pump line to 2 7/8" production tubing to set Tri-point packer. Tri-point service Rep onsite. Pressure test pump line to wing valve 250/4000 psi. Pressure up tubing to 3627 psi. Hold pressure for 30 minutes. Ending pressure after 30 minutes was 3526 psi. Drop of 101 psi during packer setting. Bleed pressure back to tank. RDMO hot oil truck and send graphs to town. 08/22/2023 - Tuesday SL Arrive, TGSM/JSA/Permit MIRU/ PT lubricator 150/1500 psi - Pass. RIH w/ bailer and tagged at 4387 and worked to 4431, POOH w/ green cement Continued to run 2.25" DD bailers and worked from 4431 to 4462 throughout the day. Last several runs were not able to make much progress, and only recovering small amounts of green cement in the bailer. Rig down secure well. Close out permits. Wait on coil to mill cement 08/29/2023 - Tuesday PJSM and PTW, Simops with production SITP 0psi. MIRU SLB Coil tubing and N2, spot R4R tanks. Stump test BOPEs - Good N/U BOPEs. Fill supply tank with 300bbl of fresh water. P/U lubricator and stab on well Fluid pack coil tubing. Pressure test BOPEs per AOGCC and Hilcorp requirements to 250psi/3000psi - Test Good AOGCC witness waived by Jim Regg via email on 8/28/23 @ 10:51AM F/P on CMV #3, valve was serviced and retested good. Pop off well, M/U YJ 2.125"od CTC, pull test to 25k, pressure test to 4500psi - test good Rack back lubricator and injector head Secure well and SDFN 08/21/2023 - Monday Rig Start Date End Date 8/14/23 8/31/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 42-12 50-133-20689-00-00 220-045 08/30/2023 - Wednesday PJSM and PTW SITP 0psi. Pick up injector head and lubricator. Pull test 2.125"OD CTC to 25k. M/U dual check valve, jars, disconnect, circ sub, pressure test connections to 4,000psi M/U mud motor and 2.29" OD 4 bladed mill. M/U lub to BOPES, pressure test lubricator and pump iron to 250psi/3000psi - Test Good. Open well and RIH Dry tag at 4,447'. Come online with pump at 1.2BPM & 3,150psi Mill cement down to 4,650' with a few stalls. Circulate 2x bottoms up. Drop ball to open circulating sub, pump on seat, open circ sub. Come online with N2 at 1500SCFM Jet well dry 48BBLs recovered (46bbl expected) POOH. Stab off well, L/D YJ BHA. Mill in very good condition. R/D SLB coil tubing Haul returns to G&I. Secure well and SDFN Rig Start Date End Date 8/14/23 8/31/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 42-12 50-133-20689-00-00 220-045 08/31/2023 - Thursday PJSM and PTW SITP 385psi. MIRU YJ E-line Pressure up well with 665psi of sales gas Swap tree connection to 2.5" Bowen. M/U gun gamma, and a 9ft 2"od Geodynamics 6SPF, 6.8gm gun (CCL to top shot 9.0ft) Pressure test lubricator to 250psi/2000psi - Test good Open well, RIH Pull correlation log, send to town. Shift down 1ft. Pull on depth and perforate Pool 4 B2 sands from 4,560-4,569'. Gun got temporarily detained but was worked free. POOH,all shots fired, gun was dry. SITP 0min - 665psi No pressure change in 15min. Secure well and open to production to flow. Minimal flow achieved, bled tubing pressure down to 15psi with no sustained flow M/U and RIH with GPT, tagged PBTD 4,646' @ 15:05 fluid level at 4,205', top perf 4,560ft, SITP 16psi. @ 15:30 fluid level at 4,170', SITP 16psi. @ 16:00 fluid level at 4,130', SITP 270psi of sales gas added @ 16:20 fluid level at 4,085', SITP 312psi of sales gas. M/U CCL and 9ft, 1-11/16 geodynamics 6SPF, 11.4gm spiral strip guns (CCL to top shot 3.5') RIH, Pull correlation log, pull on depth and re-perforate Pool 4 B2 sands from 4,560-4,569'. POOH,all shots fired. SITP 0min - 382psi No pressure change in 15min. Secure well R/D YJ E-line. Updated by CAH 09-29-23 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486 MD / TVD = 4,821 TD = 6,521 MD / TVD = 5,838 RKB to GL = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84 X-56 Weld 15.01 Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875 Surf 1,778 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892 1,636 6,521 5-1/2 Tieback Tubing 17 L-80 CDC HTQ 4.892 Surf 1,639 2-7/8 Tubing 6.4 L-80 EUE 8RD 2.441 Surf 4,739 1 2 16 7-5/8 9-7/8 hole 5-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 1,636 5-1/2 ZXP Liner Hanger Packer 2 1,639 4.800 6.030 Baker Tieback Assy. 3 3,056 2.380 4.625 DHL hydraulic set packer set post rig (08/21/23) 4 4,707 2.100 3.687 OSP HPHT Float Collar (CI) 5 5,513 CIBP w/ 26 cement TOC 5,486 07/22/20 6 5,820 CIBP 06/18/20 6-3/4 hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status P3A7 4,203 4,216 3,580' 3,592' 13' 07/29/20 3-3/8 Isolated P4B2 4,560 4,569 3,913 3,922 9 08/31/23 2-1/16 Open UB 3 5,600 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8 Isolated UB 5B 5,760 5,764 5,088 5,092 4 06/18/20 3-3/8 Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8 Isolated A7 5 6 UB 5B UB 3 B2 CBL TOC ±1,874 Fill and wireline fish at ~5,520 MD UB 5B TOC from CBL 8-21-23 @ 3,542 3 4 CT tag 8-21-23 @ 4,650 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: 09/12/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230912 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 18RD 50133205840100 222033 9/6/2023 YELLOW JACKET GPT-PERF BCU 18RD 50133205840100 222033 8/24/2023 YELLOW JACKET PLUG BCU 18RD 50133205840100 222033 8/28/2023 YELLOW JACKET PLUG-PERF BCU 18RD 50133205840100 222033 9/9/2023 YELLOW JACKET PLU-GPT-PERF BCU 18RD 50133205840100 222033 9/4/2023 YELLOW JACKET SCBL BRU 211-35 50283201890000 223050 7/31/2023 AK E-LINE CBL BRU 211-35 50283201890000 223050 8/19/2023 AK E-LINE GPT/Plug/Perf BRU 211-35 50283201890000 223050 8/10/2023 AK E-LINE Perf BRU 212-26 50283201820000 220058 8/20/2023 AK E-LINE GPT IRU 11-06 50283201300000 208184 8/1/2023 AK E-LINE Perf IRU 41-01 50283200880000 192109 9/3/2023 AK E-LINE GPT/Perf KTU 43-6XRD2 50133203280200 205117 9/4/2023 YELLOW JACKET CALIPER KU 42-12 50133206890000 220045 8/31/2023 YELLOW JACKET GPT-PERF KU 42-12 50133206890000 220045 8/20/2023 YELLOW JACKET SCBL MPU E-23 50029225700000 195094 8/18/2023 YELLOW JACKET CBL-PLUG MPU E-23 50029225700000 195094 8/20/2023 YELLOW JACKET PERF Paxton 12 50133207100000 223014 8/20/2023 AK E-LINE GPT/Perf Paxton 12 50133207100000 223014 8/14/2023 AK E-LINE Patch/Perf PBU L-240 50029237030000 221086 8/30/2023 READ IPROF Please include current contact information if different from above. T37983 T37983 T37983 T37983 T37983 T37984 T37984 T37984 T37985 T37986 T37987 T37988 T37989 T37989 T37990 T37990 T37991 T37991 T37992 9/13/2023 YELLOW KU 42-12 50133206890000 220045 8/31/2023 JACKET GPT-PERF YELLOW KU 42-12 50133206890000 220045 8/20/2023 JACKET SCBL Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.13 10:28:30 -08'00' From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Noel Nocas; Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: KU 42-12 (PTD# 220-045) Sundry # 323-295 Date:Wednesday, August 30, 2023 8:37:00 AM Chad. The cement looks good and I agree with your cement top pick at 3542’ MD. Hilcorp has approval to proceed with perforating per the sundry. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, August 28, 2023 10:54 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 42-12 (PTD# 220-045) Sundry # 323-295 Thank you Bryan, As requested in the approved Sundry for KU 42-12 (PTD# 220-045), attached is the CBL that was run on KU 42-12 after the cement job. The log ended up being shallower than planned because we left some cement in the tubing. We used a float collar and pumped the plug, but there was some bypass of the cement leaving cement in the tubing. The TOC is 3542’ and good bond all the way to bottom. Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, August 25, 2023 10:57 AM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: KU 42-12 (PTD# 220-045) Sundry # 323-295 Chad, Hilcorp has approval to proceed with the CTCO and the steps listed below as part of existing sundry 323-295. Conditions of approval: CT BOP test to 3000 psi. All conditions of approval on sundry 323-295 still apply. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, August 21, 2023 12:55 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com> Subject: KU 42-12 (PTD# 220-045) Sundry # 323-295 Bryan, We completed the rig workover program on KU 42-12 (PTD# 220-045). Looks like we got the cement high enough on the cement job (TOC~3550 ft and proposed perfs at 4560’). But the problem is we also left some cement inside the tubing. We tagged with the CBL at 4417’. And therefore we need to RU coil and cleanout the well to proposed perf depths with a motor & mill. I did not put in our normal coil contingency the sundry with the following steps. Can we have approval for use coil to cleanout this well? Per the steps listed below. Attached is the current well schematic. 1. Provide 24hrs notice to AOGCC of BOP test 2. MIRU coiled tubing, PT BOPE to 3000 psi Hi 250 Low 3. RIH with coil tubing cement milling assembly, mill cement to 4650’ 4. Circulate clean fluid around 5. Jet well dry with N2 leaving 1000 psi on well 6. POOH & RDMO CTU 7. Follow procedure for the perfs Once we get the CBL log tied in and on depth I will send to you for your review and approval. Thanks Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Noel Nocas; Regg, James B (OGC) Subject:RE: KU 42-12 (PTD# 220-045) Sundry # 323-295 Date:Friday, August 25, 2023 10:56:00 AM Chad, Hilcorp has approval to proceed with the CTCO and the steps listed below as part of existing sundry 323-295. Conditions of approval: CT BOP test to 3000 psi. All conditions of approval on sundry 323-295 still apply. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, August 21, 2023 12:55 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com> Subject: KU 42-12 (PTD# 220-045) Sundry # 323-295 Bryan, We completed the rig workover program on KU 42-12 (PTD# 220-045). Looks like we got the cement high enough on the cement job (TOC~3550 ft and proposed perfs at 4560’). But the problem is we also left some cement inside the tubing. We tagged with the CBL at 4417’. And therefore we need to RU coil and cleanout the well to proposed perf depths with a motor & mill. I did not put in our normal coil contingency the sundry with the following steps. Can we have approval for use coil to cleanout this well? Per the steps listed below. Attached is the current well schematic. 1. Provide 24hrs notice to AOGCC of BOP test 2. MIRU coiled tubing, PT BOPE to 3000 psi Hi 250 Low 3. RIH with coil tubing cement milling assembly, mill cement to 4650’ 4. Circulate clean fluid around 5. Jet well dry with N2 leaving 1000 psi on well 6. POOH & RDMO CTU 7. Follow procedure for the perfs Once we get the CBL log tied in and on depth I will send to you for your review and approval. Thanks Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Updated by CAH 8/21/23 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486’ MD / TVD = 4,821’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892” 1,636’ 6,521’ 5-1/2” Tieback Tubing 17 L-80 CDC HTQ 4.892” Surf 1,639’ 2-7/8” Tubing 6.4 L-80 EUE 8RD 2.441 Surf 4,739’ 1 2 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 1,639’ 4.800 6.030 Baker Tieback Assy. 3 3,056’ 2.380 4.625 DHL hydraulic set packer (pinned xxxx) – Not set yet 4 4,707’ 2.100 3.687 OSP HPHT Float Collar(CI) 5 5,513’ CIBP w/ 26’ cement – TOC 5,486’ 07/22/20 6 5,820’ CIBP 06/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status P3A7 4,203’ 4,216’ 3,580' 3,592' 13' 07/29/20 3-3/8” Isolated P4B2 ±4,560’ ±4,569’ ±3,913’ ±3,922’ 9’ TBD 2-1/16” Proposed UB 3 5,600’ 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8” Isolated UB 5B 5,760’ 5,764’ 5,088’ 5,092’ 4’ 06/18/20 3-3/8” Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8” Isolated A7 5 6 UB 5B UB 3 CBL TOC ±1,874’ Fill and wireline fish at ~5,520’ MD UB 5B TOC from CBL 8-21-23 @3542’ 3 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KENAI UNIT 42-12 JBR 10/16/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Remote panel was not working. Electrican troubleshoot/fixed the issue. FP Test Results TEST DATA Rig Rep:Brad WhittenOperator:Hilcorp Alaska, LLC Operator Rep:Wade Hudgens Rig Owner/Rig No.:Hilcorp 401 PTD#:2200450 DATE:8/15/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopAGE230820091420 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3 MASP: 409 Sundry No: 323-295 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 7"P #1 Rams 1 2 3/8 X 3 1/2"P #2 Rams 1 Blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16 P HCR Valves 1 2 1/16 P Kill Line Valves 3 2 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2550 200 PSI Attained P14 Full Pressure Attained P32 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@ 1800 ACC Misc FP1 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P6 #1 Rams P2 #2 Rams P2 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 99 9 9 9999 9 9 FP Remote panel was not working. 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 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,521 ~5,520 Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 8,730psi 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: Chad Helgeson Contact Email:chelgeson@hilcorp.com Contact Phone:(907) 777-8405 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Set Liner 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: AOGCC USE ONLY Operations Manager Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 17# / L-80 1,639 6/3/2023 See Schematic See Schematic See Schematic See Schematic 5-1/2" 2,980psi 6,890psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEEA028142 / FEEA028143 220-045 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-133-20689-00-00 Hilcorp Alaska, LLC Kenai Unit 42-12 Sterling Upper Undef Gas Sterling 4 Gas CO 510B Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 5,513 & 5,8205,486 Kenai 1,636 Perforation Depth MD (ft): 4,885 5-1/2" 7-5/8"177 1,778 10,600psi5,8366,521 5,836 4,821 ~409 16"120 MD 120 120 Length Size m n P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:21 am, May 22, 2023 323-295 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.05.19 14:48:06 -08'00' Noel Nocas (4361) BJM 6/19/23 Perforate New Pool P Sterling 4 Gas 10-404 BOP test to 2500 psi SFD 5/27/2023 MIT-IA (5-1/2" x 2-7/8" annulus) to 1500 psi after cementing 2-7/8" long string. X Send 2-7/8" CBL to AOGCC and obtain approval to proceed before perforating Pool 4. DSR-5/22/23GCW 06/19/2023 06/19/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.19 14:17:34 -08'00' RBDMS JSB 062023 Well Prognosis Well: KU 42-12 Date: 5-18-2023 Well Name: KU 42-12 API Number: 50-133-20689-00-00 Current Status: SI Gas Producer Permit to Drill Number: 220-045 Estimated Start Date: June 7,2023 Rig: Rig 401 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Current Bottom Hole Pressure: 820 psi @ 3,580’ TVD Based on current well conditions Maximum Expected BHP: 800 psi @ 3,913 TVD Based on RFT data in 5/2020 Maximum Potential Surface Pressure: ~409 psi @ 3,913’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary KU 42-12 was drilled as a gas well targeting the Middle and Upper Beluga formations in June of 2020. No commercial gas was found and was recompleted to the Sterling Pool 3 formation in July of 2020, where it produced gas until it watered out in December 2021. The purpose of this work/sundry is to mill buckled tubing in well, set scab liner over the current open perfs in the Kenai Sterling Undefined Pool interval, cement the liner in place and add new perforations in the Kenai Sterling Pool 4 sands. Notes Regarding Wellbore Condition x Current Pressures (T/I/O): 18/0/0 x Sand/Fill tag @ 4,148’ (5/17/23) x Max Inclination: 41deg @ 2644’ x Max DLS: ~7 degrees / 100’ at 268’ MD x MIT History: o MIT-T of 5-1/2” tubing passed to 2500 psi on 6/6/20 after drilling ran completion o MIT-IA of 5-1/2” x 7-5/8” casing passed to 2500 psi on 6/6/20 during completion x 5-1/2” Cement o RCBL cement evaluation log was run 6/9/2020 o The log shows good cement up to 2,335’ and free pipe above 1874’ o There is good cement isolation between Sterling Pools RWO Procedure 1. MIRU Hilcorp rig #401 2. Fill well with produced water (~8.5ppg) and ensure well is dead 3. Set BPV or TWC 4. NU 7” BOP’s and test a. Provide 24 hr notice to AOGCC b. PT to 250psi low / 2500psi high c. Test with 2-7/8” 5. Pull BPV or TWC 6. Monitor well to ensure its static, fill well as necessary 7. MU milling/Cleanout BHA and RIH on tubing 2-7/8” 8RD EUE 8. Tag fill at 4,148’ and cleanout well to buckled casing at 4212’ (28ft of restriction) a. Establish milling parameters and mill/cleanout well to full joint past 4700’ b. If unable to get returns, pump salt pills as necessary Well Prognosis Well: KU 42-12 Date: 5-18-2023 9. POOH and laydown milling BHA Contingency: If milling/cleanout proves challenging due to lack of returns, may elect to spot or dump bail squeeze cement at perfs to heal losses, and/or aid in milling. 10.MU 2-7/8” liner/scab assembly 11.RIH with 2-7/8” liner and land above the top of fill but below 4650’ 12.Cement 2-7/8” liner in place with ~15.3 ppg cement with LCM as necessary a.Planned TOC ~3200’ in 2-7/8” x 5-1/2” Annulus b.Cement volume of ~22bbls 13. Set BPV or TWC 14. ND BOPs, NU Tree, test to 5000psi Completion procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high 3. Log CBL of 2-7/8” production liner from PBTD to above TOC a. Send results to AOGCC b. There will not be a way to test isolation between Sterling Pool 3 and Pool 4 with the scab liner, but expect the cement quality to be good and sufficient thickness (344ft) to isolate between the Pools. 4. RDMO EL 5. MIT-T to 2000psi for 30 minutes (charted) 6. MIRU SL and pressure control equipment 7. PT lubricator to 250psi low / 2000psi high 8. Swab well to tank ~27 bbls 9. RDMO SL 10. Pressure up well with facility gas to desired underbalanced pressure for perforating. Use N2 if pressure required is higher than 700 psi. Perf procedure 1. MIRU Eline, pressure test lubricator, 250psi low / 2000psi High 2. PU and RIH W/perf guns. Perforate with Perf guns 6 SPF 60 degree phasing. If necessary, bleed N2 pressure down as requested by the OE to establish a drawdown on the formation, prior to perforating. 3. Proposed Perforated Intervals: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom Pool4 B2 ±4,560' ±4,569' 9' ±3,913' ±3,922' a.Proposed perfs. also shown on the proposed schematic in red font. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. Use Gamma/CCL to correlate. d. Verify PTs are open to SCADA before perforating. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals post shot. e. This sand is in the Kenai Sterling Gas Pool 4. 4. POOH MIT-IA (5-1/2" x 2-7/8" annulus) to 1500 psi. This will verify cement job sealed above Pool 3 perfs as planned, and by extrapolating, good cement below Pool 3, providing isolation from Pool 4. -bjm Planned TOC = 3200', above top of Pool 3 perfs. -bjm and obtain approval before perforating Pool 3. -bjm There will not be a way to test isolation between Sterling Pool 3 and Pool 4 with the scab liner, This is a 2-7/8" long string, hung off in the wellhead. -bjm Well Prognosis Well: KU 42-12 Date: 5-18-2023 5. RD e-line 6. Turn well over to production 7. Test SVS as required per 20AAC.265 Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Proposed Wellhead/Tree 4. Rig 401 7” BOP Stack 5. Standard Well Procedure – N2 Operations Updated by CAH 05-18-23 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486’ MD / TVD = 4,821’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892” 1,636’ 6,521’ 5-1/2” Tieback Tubing 17 L-80 CDC HTQ 4.892” Surf 1,639’ 1/2 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 1,639’ 4.800 6.030 Baker Tieback Assy. 3 5,513’ CIBP w/ 26’ cement – TOC 5,486’ 07/22/20 4 5,820’ CIBP 06/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status A7 4,203’ 4,216’ 3,580' 3,592' 13' 07/29/20 3-3/8” Open UB 3 5,600’ 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8” Isolated UB 5B 5,760’ 5,764’ 5,088’ 5,092’ 4’ 06/18/20 3-3/8” Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8” Isolated A7 3 4 UB 5B UB 3 CBL TOC ±1,874’ Fill and wireline fish at ~5,520’ MD UB 5B Fill @ 4,148’ (5/17/23) Buckled Pipe can drift with 4.65” GR, see caliper Updated by CAH 5/18/23 PROPOSED RWO Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486’ MD / TVD = 4,821’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892” 1,636’ 6,521’ 5-1/2” Tieback Tubing 17 L-80 CDC HTQ 4.892” Surf 1,639’ 2-7/8” Tubing 6.4 L-80 EUE 8RD 2.441 Surf ±4,700’ 1 2 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 1,639’ 4.800 6.030 Baker Tieback Assy. 5 5,513’ CIBP w/ 26’ cement – TOC 5,486’ 07/22/20 6 5,820’ CIBP 06/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status P3A7 4,203’ 4,216’ 3,580' 3,592' 13' 07/29/20 3-3/8” Isolated P4B2 ±4,560’ ±4,569’ ±3,913’ ±3,922’ 9’ TBD 2-1/16” Proposed UB 3 5,600’ 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8” Isolated UB 5B 5,760’ 5,764’ 5,088’ 5,092’ 4’ 06/18/20 3-3/8” Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8” Isolated A7 3 4 UB 5B UB 3 CBL TOC ±1,874’ Fill and wireline fish at ~5,520’ MD UB 5B Proposed TOC ±3,200’ MD Kenai Gas Field KU 42-12 05/16/2023 Valve, Master, WKM-M, 2 9/16 5M FE, HWO, DD trim Valve, Upper master, WKM-M, 2 9/16 5M FE, HWO, DD trim Valve, Swab, WKM-M 2 9/16 5M FE, HWO, DD trim BHTA, Otis, 2 9/16 5M FE x 6.5 Otis quick union top Tubing head, Cactus C-HPS, 11 5M x 7 1/16 5M, w/ 2- 2 1/16 5M SSO 16'’ 7 5/8'’ 5 ½’’ Starting head, Cactus C-29L, 13 5/8 5M x 16 SOW, w/ 2- 2 1/16 5M SSO Tubing head, Cactus C-29L- HPS, 13 5/8 5M x 11 5M, w/ 2- 2 1/16 5M SSO 2 7/8'’ Tubing hanger, Cactus-EN-CL, 7 x 2 7/8 EUE 8rd lift and susp, w/ 2 ½ type H BPV profile, 1- ¼npt control line port Adapter, Cactus-EN, 7 1/16 5M Stdd x 2 9/16 5M prepped for 5 ½ extended neck hanger Kenai Gas Field KU 42-12 16 x 7 5/8 x 5 ½ x 2 7/8 EQUIPMENT HEIGHT 99.09" ADDITION FOR RING GASKETS TOTAL STACK HEIGHT 2 each @ 0.50" 99.59" OPEN AND CLOSE DATA OPEN CLOSE 2-1/16" 5M HCR 0.61 0.52 HEIGHT DATA AND WEIGHT DATA 7-1/16" 5M ANNULAR 3.21 4.57 7-1/16" 10M RAMS (PER SET) 1.3 1.3 ϳͲϭͬϭϲΗϱDEEh>Z^,&&Z ^dz> ,/',d͗ϯϬ͘ϵΗ t/',d͗ϯϬϰϮ>^ ϳͲϭͬϭϲΗϱDdzW hKW ,/',d͗ϰϰ͘ϭϵΗ t/',d͗ϲϰϬϬ>^ ϳͲϭͬϭϲΗϱDdzWh^d< ϳͲϭͬϭϲΗϱDZ/>>/E' ^WKK> ,/',d͗ϮϰΗ t/',d͗ϭϲϬϬ>^ </>>^/͗Ϯ,ϮͲϭͬϭϲΗϱDD's ,K<^/͗ϭ,ϮͲϭͬϭϲΗϱDD's Eϭ,ϮͲϭͬϭϲΗϱD,Z STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. CAUTION: 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:Chad Helgeson To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] KU 42-12 (PTD 220-045) scab liner sundry Date:Thursday, June 15, 2023 10:57:12 AM Bryan, Thanks for the questions: 1. I have purchased a float shoe for the 2-7/8”, but I am not a huge fan of the dart. I am working on finding a better dart for it. The way I am preparing to do this is to pump a nerf wiper ball behind the cement and then maintaining the cement hydrostatic pressure on the tubing to keep the cement from u-tubing. We have had really good success with this method on our cement packers. If I get comfortable with the small dart we will probably run the float shoe 2. Yes we are installing the tubing spool before we NU BOPs. The BOPs will be on top of the new spool. 3. Yes we will land new 2-7/8” tubing in new tubing spool and will test seals to 5000 psi. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 14, 2023 4:43 PM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] KU 42-12 (PTD 220-045) scab liner sundry Chad, Could you provide a bit of detail around running/cementing the 2-7/8” liner/tubing longstring? Are you planning to install float shoe? If not, how will you keep cement in place while it is setting? Installing a new tubing spool before you NU BOP’s? Landing tubing hanger in new tubing spool & testing seals? 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. 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:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: [EXTERNAL] Completed 10-403 for KU 42-12 (PTD: 220-045) 323-250 - WITHDRAWAL/CANCEL Date:Monday, May 22, 2023 10:03:58 AM From: Donna Ambruz <dambruz@hilcorp.com> Sent: Friday, May 19, 2023 3:02 PM To: Junke, Kayla M (OGC) <kayla.junke@alaska.gov>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Chad Helgeson <chelgeson@hilcorp.com> Subject: RE: [EXTERNAL] Completed 10-403 for KU 42-12 (PTD: 220-045) 323-250 - WITHDRAWAL/CANCEL Please withdraw/cancel the above-referenced sundry. A new Sundry Application will follow shortly.. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com From: Junke, Kayla M (OGC) kayla.junke@alaska.gov Sent: Friday, April 28, 2023 10:55 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Completed 10-403 for KU 42-12 (PTD: 220-045) 323-250 Hello, Attached is the completed 10-403 for KU 42-12 (PTD: 220-045) Kayla Junke Natural Resources Tech II AOGCC (907) 793-1225 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. RBDMS JSB 052423 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: CTCO 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): Kenai C.L.U. / 11. Present Well Condition Summary: Total Depth measured 6,521 feet 1513 & 5820 feet true vertical 5,838 feet ~5520 (fish)feet Effective Depth measured 5,486 feet 1,636 feet true vertical 4,821 feet 1,526 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)Tieback 5-1/2" 17# / L-80 1,639' MD 1,529' TVD ZXP Liner Hanger Pkr; 1,636' MD 1,526' TVD Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Chad Helgeson, Operations Engineer 322-203 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 chelgeson@hilcorp.com 907-777-8405 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 0 00 0 820 21 measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-045 50-133-20589-00-00 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: FEEA028142; FEEA028143 Kenai Sterling Upper Undef Gas, Kenai Sterling Pool 3, Kenai Sterling Pool 4 Kenai Unit (KU) 42-12 Plugs Junk measured Length Production Liner 4,885' Casing Structural 5,836'6,521' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,778' 8,730psi 2,980psi 6,890psi 10,600psi 1,778' 1,636' Burst Collapse 1,410psi 4,790psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 10:57 am, Apr 25, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.04.25 09:42:43 -08'00' Noel Nocas (4361) Rig Start Date End Date 4/18/22 4/4/23 AKEL crew arrives at facility and obtains permit, PJSM. Rig up eline equipment and pressure test lubricator to 250 psi low / 2500 psi high. RIH with GR/CCL and junk basket with 4.75" gauge ring. Tag up and get stuck at 4200'. Work tools and spang free with junk basket. POOH. RDMO eline and secure well. Move equipment to KU 11-07X. 04/20/2022 - Wednesday 04/19/2022 - Tuesday Fox Energy crew arrives at facility and obtains permit, PJSM. Warm up coiled tubing equipment spread. Make up BHA consisting of stinger and 1.75" JSN and stab on well. Pressure test PCE to 250 psi low / 3500 psi high. RIH and dry tag sand plug at 4190'. Pick up and come online with triplex. Fill CT and 2500' of CT x TBG annulus with 85 bbls of lease water at 1.75 BPM. Once returns are established jet into sand plug from 4190-4221', gain 4000 lbs of weight and break through bridge. Well goes on vac. Shut down pump and let sand settle out. RIH and dry tag 4827'. POOH. Break off lubricator and lay down tools. Secure equipment and well, SDFN. 05/13/2022 - Friday RU SL, PT equipment 2500# Good RIH w/ 4.68" gauge ring to 4,345'. Run 2.5" bailer to 4,345' and bail mud/clay Continue bailing to 4,382' Make GR run to 4,374' Brush 4190-4,240 with multiple passes RD leave field 04/21/2022 - Thursday Pollard crew arrives at facility and obtains permit, PJSM. MIRU slickline equipment and pressure test lubricator to 250 psi low / 2500 psi high. RIH with 4.75" gauge ring assembly and sit down at 4200'. Work tools for 30 minutes and POOH. Gauge ring has polish marks all around the outside looking like an over-torqued collar. RIH with 5" brush and pass through obstruction with no problem, POOH. RIH with 4.56" gauge ring and make it past tight spot at 4200'. Work tools across some sticky spots from 4212-4222' and clean them up. Sit down and get stuck at 4327'. Spang free and POOH. RIH with 4.75" diamond broach and tag obstruction at 4200', work tools having to jar free with 5 licks each time. Not making any hole, POOH. Broach has wear marks all around it similar to gauge ring. RIH and repeat broaching. POOH and inspect broach, looks the same - no progress made. RIH with 4.56" gauge ring and make it through obstructions with no bobbles. RDMO slickline. 04/18/2022 - Monday PTW, JSA. Fire equipment. Unload Fox float trailer and spot in coil equipment. Continue rigging up. Spot Rain for rent supply and diffusor tank. Standby for KGF Electrician to remove electrical connections from well house. Remove wellhouse. N/U BOPE stack loaded for 1.75" coil. 24 hr BOPE test witness notification sent. Jim Regg waived witness. Function test BOPE circuits. Test all rams and valves 250/3500. Good BOPE test. Install night cap and secure well. Load supply tank with produced water. Rig down YJOS Dragon rental pump from KU 11-07X. Spot pump next to coiled tubing unit. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 42-12 50-133-20689-00-00 220-045 Rig Start Date End Date 4/18/22 4/4/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 42-12 50-133-20689-00-00 220-045 Ops and reservoir team exhausted options for isolating current open sand without a rig or coil tubing. A new sundry will be submitted for completion of this work. 06/17/2022- Friday READ and AKEL crews arrive at facility and obtain permit, PJSM. Rig up eline and 24 arm memory caliper tool. Tool will not function test at surface. Program and rig up backup tool, checks out ok. Pressure test lubricator to 250 psi low / 2500 psi high. RIH with toolstring and sit down at 4222'. Make multiple attempts to pass. Timer is up and caliper opens. Log out of hole. Break off lubricator and check tools. Good data. Secure well and RDMO eline to KBU 33-06X. 05/17/2022 - Tuesday SL Arrives in filed, Completes PTW/JSA, RU & PT 2500#, test good Run BL brush, pumped 100bbl with HO Truck, while brushing tubing. Use flowline pressure to push fluid into perfs making several more passes with BL Brush. RDSL. AKEL crew arrives at facility and obtains permit, PJSM. Rig up eline and assemble 20' x 5.5" special clearance patch assembly (4.56" max OD) in lubricator. Pick up and stab on well. Pressure test to 250 psi low / 2500 psi high. RIH with patch assembly and correlate to open hole log. Tag with bottom of patch at 4203' which is the top of perforated interval. Attempt to pass obstruction. Come online with pump and bullhead 50 bbls of lease water while working patch. Unable to pass 4203'. POOH. Inspect patch, elements are in good shape and no mud is present. Body of patch has some metal scoring present. Secure well and break down patch assembly. RDMO eline. 04/04/2023- Tuesday 05/14/2022 - Saturday AKEL crew arrives at facility and obtains permit, PJSM. Rig up eline equipment and pressure test lubricator to 250 psi low / 2500 psi high. Make up 20' x 5.5" special clearance patch assembly (4.56" max OD). RIH with patch assembly and correlate to open hole log. Tag with bottom of patch at 4203' which is the top perforation. Make attempt to pass obstruction at 40, 60, 80, 100 and 120 fpm while pulling up hole in order to try and re-orient assembly. No joy. POOH. Inspect patch, bottom element is packed off with mud increasing the OD. Some very minor metal scarring marks on bottom element. Top element and rest of assembly is clean. Lay down tools, secure well and rig down eline. Updated by CAH 06-16-22 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486 MD / TVD = 4,821 TD = 6,521 MD / TVD = 5,838 RKB to GL = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84 X-56 Weld 15.01 Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875 Surf 1,778 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892 1,636 6,521 5-1/2 Tieback Tubing 17 L-80 CDC HTQ 4.892 Surf 1,639 1/2 16 7-5/8 9-7/8 hole 5-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 1,636 5-1/2 ZXP Liner Hanger Packer 2 1,639 4.800 6.030 Baker Tieback Assy. 3 5,513 CIBP w/ 26 cement TOC 5,486 07/22/20 4 5,820 CIBP 06/18/20 6-3/4 hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status A7 4,203 4,216 3,580' 3,592' 13' 07/29/20 3-3/8 Open UB 3 5,600 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8 Isolated UB 5B 5,760 5,764 5,088 5,092 4 06/18/20 3-3/8 Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8 Isolated A7 3 4 UB 5B UB 3 CBL TOC ±1,874 Fill and wireline fish at ~5,520 MD UB 5B Fill @ 4,382 (5/13/22) 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 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Kenai 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,521 ~5,520 Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 8,730psi 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: Chad Helgeson Contact Email:chelgeson@hilcorp.com Contact Phone:(907) 777-8405 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CTCO / Set Patch 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: AOGCC USE ONLY Operations Manager Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 17# / L-80 1,639 5/3/2023 See schematic See schematic 4,203 - 4,216 3,580 - 3,592 5-1/2" 2,980psi 6,890psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEEA028142 / FEEA028143 220-045 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-133-20689-00-00 Hilcorp Alaska, LLC Kenai Unit 42-12 Beluga/Up Tyonek Gas, Sterling 3 Gas, Sterling 4 Gas, Sterling Upper Undef Gas Sterling 4 Gas CO 510B Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 5,513 & 5,820 1,636 Perforation Depth MD (ft): 4,885 5-1/2" 7-5/8"177 1,778 10,600psi5,8366,521 5,4865,836 4,821 ~1617 16"120 MD 120 120 Length Size Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-250 By Kayla Junke at 9:04 am, Apr 24, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.04.21 17:09:29 -08'00' Noel Nocas (4361) X Sterling 4 Gas 10-404 X-DSR DSR-4/26/23 BOP test to 3500 psi BJM 4/27/23 Perforate New Pool MDG 4/26/2023JLC 4/28/2023 04/28/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.28 10:22:52 -08'00' RBDMS JSB 050123 Well Prognosis Well: KU 42-12 Date: 4-20-2023 Well Name:KU 42-12 API Number:50-133-20689-00-00 Current Status:SI Gas Producer Leg:N/A Estimated Start Date:May 3,2023 Rig:CT & EL Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:220-045 First Call Engineer:Chad Helgeson (907) 777-8405 (O)(907) 229-4824 (C) Second Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Current Bottom Hole Pressure: 820 psi @ 3,580’ TVD Based current well conditions Maximum Expected BHP: 2,008 psi @ 3,913 TVD Based on KU 11-07X RFT data on 4/2017 Maximum Potential Surface Pressure: ~1,617 psi @ 3,913’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary KU 42-12 was drilled as a gas well targeting the Middle and Upper Beluga formations in June of 2020. No commercial gas was found and was recompleted to the Sterling Pool 3 formation in July of 2020, where it produced gas until it watered out in December 2021. The purpose of this work/sundry is to mill buckled tubing in well, set patch over the current open perfs in the Kenai Sterling Pool 3 interval, and add new perforations in the Kenai Sterling Pool 4 sands. A continuation of Sundried work in 2022, Sundry # 322-203. Notes Regarding Wellbore Condition x Current Pressures (T/I/O): 18/0/0 x Sand/Fill tag @ 4,374’ (5/13/22) CT Milling & Patch Procedure 1. MIRU CTU, 24hr notice to AOGCC for BOP test 2. Conduct BOP test to 250psi low / 3500psi high a. RU 7” Coil BOPs 3. PU milling assembly 4.8” OD and ~17ft long 4. RIH and Mill restricted tubing from 4208-4233’ (based on caliper run 6/17/22) 5. POOH and LD Coil 6. MIRU Eline, pressure test lubricator, 250psi low / 2500psi High 7. Drift tubing for patch 8. PU Owen XSpan 5.5” 17# patch and set across Pool 3 A7 Sand (4,203-4,216’) 9. Pressure test patch to 1,000 psi. 10. LD Eline 11. RU jet nozzle on coil tubing, RIH and cleanout well to bottom (or min of 4600’) 12. Jet well dry with N2 a. Confirm with engineer of pressure to leave on well, once dry b. May reverse fluid out depending on depth of fill cleanout. 13. RDMO Coil tubing new perforations in the Kenai Sterling Pool 4 sands. Work completed in 2022: coiled tubing cleanout. No perfs shot or patches set. MDG 4/26/2023 Well Prognosis Well: KU 42-12 Date: 4-20-2023 Perf procedure 14. MIRU Eline, pressure test lubricator, 250psi low / 2500psi High 15. PU and RIH W/perf guns. Perforate with Perf guns 6 SPF 60 degree phasing. If necessary, bleed N2 pressure down as requested by the OE to establish a drawdown on the formation, prior to perforating. 16. Proposed Perforated Intervals: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom Pool4 B2 ±4,560' ±4,569' 9' ±3,913' ±3,922' a. Proposed perfs. also shown on the proposed schematic in red font. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. Use Gamma/CCL to correlate. d. Verify PTs are open to SCADA before perforating. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals post shot. e. This sand is in the Kenai Sterling Gas Pool 4. 17. POOH 18. RD e-line 19. Turn well over to production 20. Test SVS as required per 20AAC.265 Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Caliper results (4195-4245) 4. Coil tubing BOPE – 7” stack 5. Standard Well Procedure – N2 Operations Updated by CAH 06-16-22 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486’ MD / TVD = 4,821’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892” 1,636’ 6,521’ 5-1/2” Tieback Tubing 17 L-80 CDC HTQ 4.892” Surf 1,639’ 1/2 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 1,639’ 4.800 6.030 Baker Tieback Assy. 3 5,513’ CIBP w/ 26’ cement – TOC 5,486’ 07/22/20 4 5,820’ CIBP 06/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status A7 4,203’ 4,216’ 3,580' 3,592' 13' 07/29/20 3-3/8” Open UB 3 5,600’ 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8” Isolated UB 5B 5,760’ 5,764’ 5,088’ 5,092’ 4’ 06/18/20 3-3/8” Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8” Isolated A7 3 4 UB 5B UB 3 CBL TOC ±1,874’ Fill and wireline fish at ~5,520’ MD UB 5B Fill @ 4,382’ (5/13/22) Updated by CAH 4/20/23 PROPOSED Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486’ MD / TVD = 4,821’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892” 1,636’ 6,521’ 5-1/2” Tieback Tubing 17 L-80 CDC HTQ 4.892” Surf 1,639’ 1/2 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 1,639’ 4.800 6.030 Baker Tieback Assy. 3 4,200’ 4.0 4.892 Owen XSpan Permanent Patch (25’ OAL) 4 5,513’ CIBP w/ 26’ cement – TOC 5,486’ 07/22/20 5 5,820’ CIBP 06/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Size Status P3A7 4,203’ 4,216’ 3,580' 3,592' 13' 07/29/20 3-3/8” Patched P4B2 ±4,560’ ±4,569’ ±3,913’ ±3,922’ 9’ TBD 2-7/8” Proposed UB 3 5,600’ 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8” Isolated UB 5B 5,760’ 5,764’ 5,088’ 5,092’ 4’ 06/18/20 3-3/8” Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8” Isolated A7 4 5 UB 5B UB 3 CBL TOC ±1,874’ Fill and wireline fish at ~5,520’ MD UB 5B 3 7” Coiled Tubing BOP Dressed for 1.75” CT Lubricator to injection head ManualManualManual Manual Valve, master, WKM, 5-½” 5M FE, HWO Valve, swab, WKM, 5-½” 5M FE, HWO SWAB VALVE MASTER VALVE Blind/Shear Pipe/Slip 7” Coiled Tubing BOP Dressed for 1.75” CT ! "#$%& ' ($& ' )#"** %+##"** %##"** ,$"** %+##- %##- "#$%& ' ($& ' ./ / / / ( (/ / Perforations Perforations Oval Deformation at Severe Buckling. Min ID = 4.709" Deposits Min ID = 4.527" 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. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 42-12 (PTD 220-045) Caliper Survey 06/17/2022 Please include current contact information if different from above. PTD:220-045 T36732 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.29 10:38:28 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Cole Bartlewski To:Regg, James B (OGC);Brooks, Phoebe L (OGC);DOA AOGCC Prudhoe Bay Cc:Juanita Lovett Subject:BOPE test report for Fox CTU 8 on KU 42-12 Date:Friday, April 22, 2022 12:09:34 PM Attachments:Fox_CTU_8_4_18_22_KU_42_12_BOPE_TEST.xlsx Good afternoon. BOPE test report attached. Have a great weekend. Cole Bartlewski Hilcorp Alaska, LLC Sr. Wellsite Supervisor/ 401 Rig Manager Email:cbartlewski@hilcorp.com Office 907-283-1301 Cell 907-690-2854 Hilcorp Alaska, LLC A Company built on Energy 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. .HQDL8QLW 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Contractor: Rig No.:8 DATE: 4/18/22 Rig Rep.: Rig Phone: 907-887-1766 Operator: Op. Phone:907-632-4113 Rep.: E-Mail Well Name: PTD #22200450 Sundry #322-203 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Rams:250/3500 Annular:N/A Valves:250/3500 MASP:1617 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 N/A NA Pit Level Indicators NA NA #1 Rams 1 1.75" B/S P Flow Indicator NA NA #2 Rams 1 1.75" P/S P Meth Gas Detector NA NA #3 Rams 0 N/A NA H2S Gas Detector NA NA #4 Rams 0 N/A NA MS Misc 0NA #5 Rams 0 N/A NA #6 Rams 0 N/A NA Quantity Test Result Choke Ln. Valves 2 2"P Inside Reel valves 1P HCR Valves 0 N/A NA Kill Line Valves 2 2"P Check Valve 0 N/A NA ACCUMULATOR SYSTEM: BOP Misc 0 N/A NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2200 P Quantity Test Result 200 psi Attained (sec)4 P No. Valves 5P Full Pressure Attained (sec)13 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): N/A NA CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.0 Hours Repair or replacement of equipment will be made within N/A days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/17/22@2023 Waived By Test Start Date/Time:4/18/2022 12:30 (date) (time)Witness Test Finish Date/Time:4/18/2022 4:30 PM BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Accumulator Bottle pre-charge pressure =1400 psi. Landry Lynn Hilcorp Alaska Cole Bartlewski KU 42-12 Test Pressure (psi): cbartlewski@hilcorp.com Form 10-424 (Revised 04/2018) 2022-0418_BOP_Fox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a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a 3 W V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 2:52 pm, Apr 11, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH BJM 4/14/22 10-404 3HUIRUDWH1HZ3 RRO3 SFD 4/11/2022 .HQDL6WHUOLQJ3RRO 3HUIRUDWH CT BOP test to 3500 psi. X DSR-4/11/22 dts 4/14/2022 JLC 4/14/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.04.15 09:54:47 -08'00' RBDMS SJC 041822 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗<hϰϮͲϭϮ ĂƚĞ͗ϰͲϱͲϮϬϮϮ tĞůůEĂŵĞ͗<hϰϮͲϭϮW/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϲϴϵͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/'ĂƐWƌŽĚƵĐĞƌ>ĞŐ͗Eͬ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗Ɖƌŝůϭϵ͕ϮϬϮϮZŝŐ͗dΘ> ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌϳϳϳͲϴϯϬϱWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϮϬͲϬϰϱ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;Ϳ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;KͿ;ϵϬϳͿϯϬϭͲϭϳϯϲ;Ϳ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϴϮϬƉƐŝΛϯ͕ϱϴϬ͛dsĂƐĞĚĐƵƌƌĞŶƚǁĞůůĐŽŶĚŝƚŝŽŶƐ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗Ϯ͕ϬϬϴƉƐŝΛϯ͕ϵϭϯdsĂƐĞĚŽŶ<hϭϭͲϬϳyZ&dĚĂƚĂŽŶϰͬϮϬϭϳ DĂǆŝŵƵŵWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗Εϭ͕ϲϭϳƉƐŝΛϯ͕ϵϭϯ͛dshƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚϮϬϮϱ͘ϮϴϬ;ďͿ;ϰͿ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ <hϰϮͲϭϮǁĂƐĚƌŝůůĞĚĂƐĂŐĂƐǁĞůůƚĂƌŐĞƚŝŶŐƚŚĞDŝĚĚůĞĂŶĚhƉƉĞƌĞůƵŐĂĨŽƌŵĂƚŝŽŶƐŝŶ:ƵŶĞŽĨϮϬϮϬ͘EŽ ĐŽŵŵĞƌĐŝĂůŐĂƐǁĂƐĨŽƵŶĚĂŶĚǁĂƐƌĞĐŽŵƉůĞƚĞĚƚŽƚŚĞ^ƚĞƌůŝŶŐWŽŽůϯĨŽƌŵĂƚŝŽŶŝŶ:ƵůǇŽĨϮϬϮϬ͕ǁŚĞƌĞŝƚ ƉƌŽĚƵĐĞĚŐĂƐƵŶƚŝůŝƚǁĂƚĞƌĞĚŽƵƚŝŶĞĐĞŵďĞƌϮϬϮϭ͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐǁŽƌŬͬƐƵŶĚƌǇŝƐƚŽƉĞƌĨŽƌŵĂĐŽŝůĐůĞĂŶŽƵƚŽĨƚŚĞǁĞůů͕ƐĞƚƉĂƚĐŚŽǀĞƌƚŚĞĐƵƌƌĞŶƚŽƉĞŶƉĞƌĨƐ ŝŶƚŚĞ<ĞŶĂŝ^ƚĞƌůŝŶŐWŽŽůϯŝŶƚĞƌǀĂů͕ĂŶĚĂĚĚŶĞǁƉĞƌĨŽƌĂƚŝŽŶƐŝŶƚŚĞ<ĞŶĂŝ^ƚĞƌůŝŶŐWŽŽůϰƐĂŶĚƐ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x ƵƌƌĞŶƚWƌĞƐƐƵƌĞƐ;dͬ/ͬKͿ͗ϵϱͬϬͬϬ x &ůƵŝĚƚĂŐΛϮ͕ϱϱϬ͛;ĞĐ͘ϭϱ͕ϮϬϮϭͿ x ^ĂŶĚͬ&ŝůůƚĂŐΛϰ͕Ϯϭϰ͛;ĞĐ͘ϭϱ͕ϮϬϮϭͿ ůĞĂŶŽƵƚΘWĂƚĐŚWƌŽĐĞĚƵƌĞ ϭ͘ D/Zhdh͕ϮϰŚƌŶŽƚŝĐĞƚŽK'ĨŽƌKWƚĞƐƚ Ϯ͘ ŽŶĚƵĐƚKWƚĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝŚŝŐŚ ϯ͘ Z/,ǁŝƚŚǁĂƐŚŶŽǌǌůĞĂŶĚĐůĞĂŶǁĞůůŽƵƚƚŽďŽƚƚŽŵ Ă͘ hƐĞEϮĂŶĚĨŽĂŵŝĨŶĞĐĞƐƐĂƌǇƚŽŐĞƚƌĞƚƵƌŶƐ ď͘ tĂƐŚƚŚƌŽƵŐŚŽƉĞŶƉĞƌĨƐƐĞǀĞƌĂůƚŝŵĞƐƚŽĐůĞĂŶǁĂůůĨŽƌƉĂƚĐŚ ϰ͘ WKK,ĂŶĚ>Žŝů ϱ͘ D/ZhůŝŶĞ͕ƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌ͕ϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝ,ŝŐŚ ϲ͘ ƌŝĨƚƚƵďŝŶŐĨŽƌƉĂƚĐŚ ϳ͘ WhKǁĞŶy^ƉĂŶϱ͘ϱ͟ϭϳηƉĂƚĐŚĂŶĚƐĞƚĂĐƌŽƐƐWŽŽůϯϳ^ĂŶĚ;ϰ͕ϮϬϯͲϰ͕Ϯϭϲ͛Ϳ ϴ͘ >ůŝŶĞ ϵ͘ ZhũĞƚŶŽǌǌůĞŽŶĐŽŝůƚƵďŝŶŐ͕Z/,ĂŶĚũĞƚǁĞůůĚƌǇǁŝƚŚEϮ Ă͘ ŽŶĨŝƌŵǁŝƚŚĞŶŐŝŶĞĞƌŽĨƉƌĞƐƐƵƌĞƚŽůĞĂǀĞŽŶǁĞůů͕ŽŶĐĞĚƌǇ ϭϬ͘ ZDKŽŝůƚƵďŝŶŐ WĞƌĨƉƌŽĐĞĚƵƌĞ ϭϭ͘ D/ZhůŝŶĞ͕ƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌ͕ϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝ,ŝŐŚ ĂĚĚŶĞǁƉĞƌĨŽƌĂƚŝŽŶƐŝŶƚŚĞ<ĞŶĂŝ^ƚĞƌůŝŶŐWŽŽůϰƐ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗<hϰϮͲϭϮ ĂƚĞ͗ϰͲϱͲϮϬϮϮ ϭϮ͘ WhĂŶĚZ/,tͬƉĞƌĨŐƵŶƐ͘WĞƌĨŽƌĂƚĞǁŝƚŚϮͲϳͬϴ͟WĞƌĨŐƵŶƐϲ^W&ϲϬĚĞŐƌĞĞƉŚĂƐŝŶŐ͘/ĨŶĞĐĞƐƐĂƌǇ͕ďůĞĞĚ EϮƉƌĞƐƐƵƌĞĚŽǁŶĂƐƌĞƋƵĞƐƚĞĚďǇƚŚĞKƚŽĞƐƚĂďůŝƐŚĂĚƌĂǁĚŽǁŶŽŶƚŚĞĨŽƌŵĂƚŝŽŶ͕ƉƌŝŽƌƚŽ ƉĞƌĨŽƌĂƚŝŶŐ͘ ϭϯ͘ WƌŽƉŽƐĞĚWĞƌĨŽƌĂƚĞĚ/ŶƚĞƌǀĂůƐ͗ ^ĂŶĚDdŽƉDŽƚƚŽŵdŽƚĂů&ŽŽƚĂŐĞ ;DͿdsdŽƉdsŽƚƚŽŵ WŽŽůϰϮцϰ͕ϱϲϬΖцϰ͕ϱϲϵΖϵΖцϯ͕ϵϭϯΖцϯ͕ϵϮϮΖ Ă͘3URSRVHGSHUIVDOVRVKRZQRQWKHSURSRVHGVFKHPDWLFLQUHGIRQW E )LQDO3HUIVWLHLQVKHHWZLOOEHSURYLGHGLQWKHILHOGIRUH[DFWSHUILQWHUYDOV F &RUUHODWHXVLQJ2SHQ+ROH&RUUHODWLRQ/RJSURYLGHGE\*HRORJLVW6HQGWKHFRUUHODWLRQSDVV WRWKH2SHUDWLRQV(QJLQHHU5HVHUYRLU(QJLQHHUDQG*HRORJLVWIRUFRQILUPDWLRQ d. Use Gamma/CCL to correlate. H ,QVWDOO&U\VWDOJDXJHVRUYHULI\37VDUHRSHQWR6&$'$EHIRUHSHUIRUDWLQJ5HFRUGWXELQJ SUHVVXUHVEHIRUHDQGDIWHUHDFKSHUIRUDWLQJUXQDWPLQPLQDQGPLQLQWHUYDOVSRVW VKRW I 7KLVVDQGLVLQWKH.HQDL6WHUOLQJ*DV3RRO ϭϰ͘ WKK, ϭϱ͘ ZĞͲůŝŶĞ ϭϲ͘dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůƚƵďŝŶŐKW ϰ͘ ^ƚĂŶĚĂƌĚtĞůůWƌŽĐĞĚƵƌĞʹEϮKƉĞƌĂƚŝŽŶƐ .HQDL6WHUOLQJ*DV3RRO WŽŽůϰϮ hƉĚĂƚĞĚďǇ,ϰͬϯͬϮϮ ^,Dd/ <ĞŶĂŝ'ĂƐ&ŝĞůĚ <hϰϮͲϭϮ Wd͗ϮϮϬͲϬϰϱ W/͗ϱϬͲϭϯϯͲϮϬϲϴϵͲϬϬͲϬϬ Wdсϱ͕ϰϴϲ͛Dͬdsсϰ͕ϴϮϭ͛ dсϲ͕ϱϮϭ͛Dͬdsсϱ͕ϴϯϴ͛ Z<ƚŽ'>сϭϴ͛ ^/E'd/> ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶ͘/dŽƉƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶ ƚŽ^ĞƚĞƉƚŚϴϰyͲϱϲtĞůĚ ϭϱ͘Ϭϭ͟^ƵƌĨϭϮϬΖ ϳͲϱͬϴΗ^ƵƌĨƐŐϮϵ͘ϳ>ͲϴϬtͬϲ͘ϴϳϱ͟^ƵƌĨϭ͕ϳϳϴ͛ ϱͲϭͬϮΗWƌŽĚ>ŝŶĞƌϭϳ>ͲϴϬ,dYϰ͘ϴϵϮ͟ϭ͕ϲϯϲ͛ϲ͕ϱϮϭ͛ ϱͲϭͬϮ͟dŝĞďĂĐŬdƵďŝŶŐϭϳ>ͲϴϬ,dYϰ͘ϴϵϮ͟^ƵƌĨϭ͕ϲϯϵ͛ ϭͬϮ ϭϲ͟ ϳͲϱͬϴ͟ ϵͲϳͬϴ͟ ŚŽůĞ ϱͲϭͬϮ͟ :t>Zzd/> EŽ͘ĞƉƚŚ/K/ƚĞŵ ϭϭ͕ϲϯϲ͛ϱͲϭͬϮ͟yW>ŝŶĞƌ,ĂŶŐĞƌWĂĐŬĞƌ Ϯϭ͕ϲϯϵ͛ϰ͘ϴϬϬϲ͘ϬϯϬĂŬĞƌdŝĞďĂĐŬƐƐǇ͘ ϯϱ͕ϱϭϯ͛/WǁͬϮϲ͛ĐĞŵĞŶƚʹdKϱ͕ϰϴϲ͛ϬϳͬϮϮͬϮϬ ϰϱ͕ϴϮϬ͛/WϬϲͬϭϴͬϮϬ ϲͲϯͬϰ͟ ŚŽůĞ WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ&dĂƚĞ ^ŝǌĞ^ƚĂƚƵƐ ϳϰ͕ϮϬϯ͛ϰ͕Ϯϭϲ͛ϯ͕ϱϴϬΖϯ͕ϱϵϮΖϭϯΖϬϳͬϮϵͬϮϬϯͲϯͬϴ͟KƉĞŶ hϯϱ͕ϲϬϬ͛ϱ͕ϲϬϮΖϰ͕ϵϯϮΖϰ͕ϵϯϰΖϮΖϬϲͬϭϵͬϮϬϯͲϯͬϴ͟/ƐŽůĂƚĞĚ hϱϱ͕ϳϲϬ͛ϱ͕ϳϲϰ͛ϱ͕Ϭϴϴ͛ϱ͕ϬϵϮ͛ϰ͛ϬϲͬϭϴͬϮϬϯͲϯͬϴ͟/ƐŽůĂƚĞĚ hϱϱ͕ϴϱϯΖϱ͕ϴϲϯΖϱ͕ϭϴϬΖϱ͕ϭϵϬΖϭϬΖϬϲͬϬϵͬϮϬϯͲϯͬϴ͟/ƐŽůĂƚĞĚ ϳ ϯ ϰ hϱ hϯ >dK цϭ͕ϴϳϰ͛ &ŝůůĂŶĚǁŝƌĞůŝŶĞĨŝƐŚĂƚ Εϱ͕ϱϮϬ͛D hϱ &ŝůůΛϰ͕ϮϭϮ͛;ϭϮͬϭϱͬϮϭͿ hƉĚĂƚĞĚďǇ,ϰͬϯͬϮϮ WZKWK^ <ĞŶĂŝ'ĂƐ&ŝĞůĚ <hϰϮͲϭϮ Wd͗ϮϮϬͲϬϰϱ W/͗ϱϬͲϭϯϯͲϮϬϲϴϵͲϬϬͲϬϬ Wdсϱ͕ϰϴϲ͛Dͬdsсϰ͕ϴϮϭ͛ dсϲ͕ϱϮϭ͛Dͬdsсϱ͕ϴϯϴ͛ Z<ƚŽ'>сϭϴ͛ ^/E'd/> ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶ͘/dŽƉƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶ ƚŽ^ĞƚĞƉƚŚϴϰyͲϱϲtĞůĚ ϭϱ͘Ϭϭ͟^ƵƌĨϭϮϬΖ ϳͲϱͬϴΗ^ƵƌĨƐŐϮϵ͘ϳ>ͲϴϬtͬϲ͘ϴϳϱ͟^ƵƌĨϭ͕ϳϳϴ͛ ϱͲϭͬϮΗWƌŽĚ>ŝŶĞƌϭϳ>ͲϴϬ,dYϰ͘ϴϵϮ͟ϭ͕ϲϯϲ͛ϲ͕ϱϮϭ͛ ϱͲϭͬϮ͟dŝĞďĂĐŬdƵďŝŶŐϭϳ>ͲϴϬ,dYϰ͘ϴϵϮ͟^ƵƌĨϭ͕ϲϯϵ͛ ϭͬϮ ϭϲ͟ ϳͲϱͬϴ͟ ϵͲϳͬϴ͟ ŚŽůĞ ϱͲϭͬϮ͟ :t>Zzd/> EŽ͘ĞƉƚŚ/K/ƚĞŵ ϭϭ͕ϲϯϲ͛ϱͲϭͬϮ͟yW>ŝŶĞƌ,ĂŶŐĞƌWĂĐŬĞƌ Ϯϭ͕ϲϯϵ͛ϰ͘ϴϬϬϲ͘ϬϯϬĂŬĞƌdŝĞďĂĐŬƐƐǇ͘ ϯϰ͕ϮϬϬ͛ϰ͘Ϭϰ͘ϴϵϮKǁĞŶy^ƉĂŶWĞƌŵĂŶĞŶƚWĂƚĐŚ ϰϱ͕ϱϭϯ͛/WǁͬϮϲ͛ĐĞŵĞŶƚʹdKϱ͕ϰϴϲ͛ϬϳͬϮϮͬϮϬ ϱϱ͕ϴϮϬ͛/WϬϲͬϭϴͬϮϬ ϲͲϯͬϰ͟ ŚŽůĞ WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ&dĂƚĞ ^ŝǌĞ^ƚĂƚƵƐ Wϯϳϰ͕ϮϬϯ͛ϰ͕Ϯϭϲ͛ϯ͕ϱϴϬΖϯ͕ϱϵϮΖϭϯΖϬϳͬϮϵͬϮϬϯͲϯͬϴ͟WĂƚĐŚĞĚ WϰϮцϰ͕ϱϲϬ͛цϰ͕ϱϲϵ͛цϯ͕ϵϭϯ͛цϯ͕ϵϮϮ͛ϵ͛dϮͲϳͬϴ͟WƌŽƉŽƐĞĚ hϯϱ͕ϲϬϬ͛ϱ͕ϲϬϮΖϰ͕ϵϯϮΖϰ͕ϵϯϰΖϮΖϬϲͬϭϵͬϮϬϯͲϯͬϴ͟/ƐŽůĂƚĞĚ hϱϱ͕ϳϲϬ͛ϱ͕ϳϲϰ͛ϱ͕Ϭϴϴ͛ϱ͕ϬϵϮ͛ϰ͛ϬϲͬϭϴͬϮϬϯͲϯͬϴ͟/ƐŽůĂƚĞĚ hϱϱ͕ϴϱϯΖϱ͕ϴϲϯΖϱ͕ϭϴϬΖϱ͕ϭϵϬΖϭϬΖϬϲͬϬϵͬϮϬϯͲϯͬϴ͟/ƐŽůĂƚĞĚ ϳ ϰ ϱ hϱ hϯ >dK цϭ͕ϴϳϰ͛ &ŝůůĂŶĚǁŝƌĞůŝŶĞĨŝƐŚĂƚ Εϱ͕ϱϮϬ͛D hϱ ϯ ^dEZt>>WZKhZ E/dZK'EKWZd/KE^ ϭϮͬϬϴͬϮϬϭϱ &/E>ǀϭ WĂŐĞϭŽĨϭ ϭ͘Ϳ D/ZhEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Ϯ͘Ϳ EŽƚŝĨǇWĂĚKƉĞƌĂƚŽƌŽĨƵƉĐŽŵŝŶŐEŝƚƌŽŐĞŶŽƉĞƌĂƚŝŽŶƐ͘ ϯ͘Ϳ WĞƌĨŽƌŵWƌĞͲ:Žď^ĂĨĞƚǇDĞĞƚŝŶŐ͘ZĞǀŝĞǁEŝƚƌŽŐĞŶǀĞŶĚŽƌƐƚĂŶĚĂƌĚŽƉĞƌĂƚŝŶŐƉƌŽĐĞĚƵƌĞƐĂŶĚ ĂƉƉƌŽƉƌŝĂƚĞ^ĂĨĞƚǇĂƚĂ^ŚĞĞƚƐ;ĨŽƌŵĞƌůǇD^^Ϳ͘ ϰ͘Ϳ ŽĐƵŵĞŶƚ ŚĂǌĂƌĚƐ ĂŶĚ ŵŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ĂŶĚ ĐŽŶĨŝƌŵ ĨůŽǁ ƉĂƚŚƐ͘ /ŶĐůƵĚĞ ƌĞǀŝĞǁ ŽŶ ĂƐƉŚǇǆŝĂƚŝŽŶ ĐĂƵƐĞĚ ďǇ ŶŝƚƌŽŐĞŶĚŝƐƉůĂĐŝŶŐŽǆǇŐĞŶ͘DŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ŝŶĐůƵĚĞĂƉƉƌŽƉƌŝĂƚĞ ƌŽƵƚŝŶŐŽĨĨůŽǁůŝŶĞƐ͕ĂĚĞƋƵĂƚĞǀĞŶƚŝŶŐĂŶĚĂƚŵŽƐƉŚĞƌŝĐŵŽŶŝƚŽƌŝŶŐ͘ ϱ͘Ϳ ^ƉŽƚWƵŵƉŝŶŐhŶŝƚĂŶĚdƌĂŶƐƉŽƌƚ͘ŽŶĨŝƌŵůŝƋƵŝĚEϮǀŽůƵŵĞƐŝŶƚƌĂŶƐƉŽƌƚ͘ ϲ͘Ϳ ZŝŐƵƉůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚƚŽƚŚĞǁĞůůĂŶĚƌĞƚƵƌŶƐƚĂŶŬ͘^ĞĐƵƌĞůŝŶĞƐǁŝƚŚǁŚŝƉ ĐŚĞĐŬƐ͘ ϳ͘Ϳ WůĂĐĞ ƐŝŐŶƐ ĂŶĚ ƉůĂĐĂƌĚƐ ǁĂƌŶŝŶŐ ŽĨ ŚŝŐŚ ƉƌĞƐƐƵƌĞ ĂŶĚ ŶŝƚƌŽŐĞŶ ŽƉĞƌĂƚŝŽŶƐ Ăƚ ĂƌĞĂƐ ǁŚĞƌĞ EŝƚƌŽŐĞŶŵĂǇĂĐĐƵŵƵůĂƚĞŽƌďĞƌĞůĞĂƐĞĚ͘ ϴ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐĚŽǁŶƐƚƌĞĂŵŽĨůŝƋƵŝĚĂŶĚŶŝƚƌŽŐĞŶƉƵŵƉƐƚŽĂĚĞƋƵĂƚĞůǇŵĞĂƐƵƌĞƚƵďŝŶŐ ĂŶĚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐ͘ ϵ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƵƉƐƚƌĞĂŵĂŶĚĚŽǁŶƐƚƌĞĂŵŽĨĂŶǇĐŚĞĐŬǀĂůǀĞƐ͘ ϭϬ͘Ϳ tĞůůƐŝƚĞDĂŶĂŐĞƌƐŚĂůůǁĂůŬĚŽǁŶǀĂůǀĞĂůŝŐŶŵĞŶƚƐĂŶĚĞŶƐƵƌĞǀĂůǀĞƉŽƐŝƚŝŽŶŝƐĐŽƌƌĞĐƚ͘ ϭϭ͘Ϳ ŶƐƵƌĞƉŽƌƚĂďůĞϰͲŐĂƐĚĞƚĞĐƚŝŽŶĞƋƵŝƉŵĞŶƚŝƐŽŶƐŝƚĞ͕ĐĂůŝďƌĂƚĞĚ͕ĂŶĚďƵŵƉƚĞƐƚĞĚƉƌŽƉĞƌůǇƚŽ ĚĞƚĞĐƚ>>ͬ,Ϯ^ͬKϮͬKϮůĞǀĞůƐ͘ŶƐƵƌĞEŝƚƌŽŐĞŶǀĞŶĚŽƌŚĂƐĂǁŽƌŬŝŶŐĂŶĚĐĂůŝďƌĂƚĞĚĚĞƚĞĐƚŽƌĂƐ ǁĞůůƚŚĂƚŵĞĂƐƵƌĞƐKϮůĞǀĞůƐ͘ ϭϮ͘Ϳ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƵƉƐƚƌĞĂŵŽĨǁĞůůƚŽĂƉƉƌŽǀĞĚƐƵŶĚƌǇƉƌĞƐƐƵƌĞŽƌDW^W;DĂǆŝŵƵŵWŽƚĞŶƚŝĂů ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞͿ͕ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘dĞƐƚůŝŶĞƐĚŽǁŶƐƚƌĞĂŵŽĨǁĞůů;ĨƌŽŵǁĞůůƚŽƌĞƚƵƌŶƐƚĂŶŬͿ ƚŽϭ͕ϱϬϬƉƐŝ͘WĞƌĨŽƌŵǀŝƐƵĂůŝŶƐƉĞĐƚŝŽŶĨŽƌĂŶǇůĞĂŬƐ͘ ϭϯ͘Ϳ ůĞĞĚŽĨĨƚĞƐƚƉƌĞƐƐƵƌĞĂŶĚƉƌĞƉĂƌĞĨŽƌƉƵŵƉŝŶŐŶŝƚƌŽŐĞŶ͘ ϭϰ͘Ϳ WƵŵƉŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϱ͘Ϳ tŚĞŶĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘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y Jody Colombie at 4:44 pm, Mar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anual of Back- Pressure Testing of Gas Wells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o.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, DGR, AGR, ABG, ADR, EWR MD & TVD, GeoTap, CBL 6-9-20NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF7/20/202010 6600 Electronic Data Set, Filename: KU 42-12.las33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-24-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-25-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-26-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-27-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-28-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-29-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-30-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 05-31-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 06-01-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 06-02-2020.pdf33564EDDigital DataDF7/20/2020 Electronic File: Hilcorp KU 42-12 Geolog AM Report 06-03-2020.pdf33564EDDigital DataThursday, October 15, 2020AOGCCPage 1 of 8KU 42-12.lasSupplied byOPSupplied byOP DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoDF7/20/2020 Electronic File: KU 42-12 Final Well Report.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Drilling Dynamics Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Drilling Dynamics Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Formation Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Formation Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Gas Ratio Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Gas Ratio Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in LWD Combo Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in LWD Combo Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Drilling Dynamics Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Drilling Dynamics Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Formation Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Formation Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Gas Ratio Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Gas Ratio Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - LWD Combo Log MD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - LWD Combo Log TVD.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Drilling Dynamics Log MD.tif33564EDDigital DataThursday, October 15, 2020AOGCCPage 2 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoDF7/20/2020 Electronic File: KU_42-12 - 5in Drilling Dynamics Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Formation Log MD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Formation Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Gas Ratio Log MD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in Gas Ratio Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in LWD Combo Log MD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - 5in LWD Combo Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Drilling Dynamics Log MD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Drilling Dynamics Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Formation Log MD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Formation Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Gas Ratio Log MD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - Gas Ratio Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - LWD Combo Log 33564EDDigital DataDF7/20/2020 Electronic File: KU_42-12 - LWD Combo Log TVD.tif33564EDDigital DataDF7/20/2020 Electronic File: KU42-12.dbf33564EDDigital DataDF7/20/2020 Electronic File: ku42-12.hdr33564EDDigital DataDF7/20/2020 Electronic File: KU42-12.mdx33564EDDigital DataDF7/20/2020 Electronic File: ku42-12r.dbf33564EDDigital DataDF7/20/2020 Electronic File: ku42-12r.mdx33564EDDigital DataThursday, October 15, 2020AOGCCPage 3 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoDF7/20/2020 Electronic File: KU42-12_DML.zip33564EDDigital DataDF7/20/2020 Electronic File: KU42-12_SCL.DBF33564EDDigital DataDF7/20/2020 Electronic File: KU42-12_SCL.MDX33564EDDigital DataDF7/20/2020 Electronic File: KU42-12_tvd.dbf33564EDDigital DataDF7/20/2020 Electronic File: KU42-12_tvd.mdx33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 1 4015-4045.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 10 5720-5730.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 11 5845-5880.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 12 5970-6010.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 13 6050-6064.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 14 6170-6210.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 15 6240-6260.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 2 4200-4230.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 3 4360-4380.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 4 4386-4412.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 5 4560-4570.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 6 5450-5460.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 7 5515-5540.pdf33564EDDigital DataThursday, October 15, 2020AOGCCPage 4 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 8 5595-5612.pdf33564EDDigital DataDF7/20/2020 Electronic File: KU 42-12 Gas Show Report 9 5625-5650.pdf33564EDDigital Data0 0 2200450 KENAI UNIT 42-12 LOG HEADERS33564LogLog Header ScansDF8/19/2020118 6522 Electronic Data Set, Filename: KU 42-12 LWD Final.las33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 LWD Final MD.cgm33671EDDigital DataDF8/19/2020 Electronic File: DSR KU 42-12_Plan.pdf33671EDDigital DataDF8/19/2020 Electronic File: DSR KU 42-12_VSec.pdf33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 - Definitive Survey Report.pdf33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 - Definitive Surveys.xlsx33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12_DSR.txt33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12_GIS.txt33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 1.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 10.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 11.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 12.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 13.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 14.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 15.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 16.asc33671EDDigital DataThursday, October 15, 2020AOGCCPage 5 of 8KU 42-12 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 17.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 18.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 19.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 2.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 20.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 21.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 22.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 23.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 24.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 25.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 26.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 27.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 28.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 29.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 3.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 4.asc33671EDDigital DataThursday, October 15, 2020AOGCCPage 6 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 5.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 6.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 7.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 8.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 Geotap Test 9.asc33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 LWD Final MD.pdf33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 LWD Final TVD.pdf33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 GeoTap Recorded Pressure Tests.pdf33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 LWD Final MD.tif33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 LWD Final TVD.tif33671EDDigital DataDF8/19/2020 Electronic File: KU 42-12 Run 400 GeoTap Recorded Pressure Tests.tif33671EDDigital Data0 0 2200450 KENAI UNIT 42-12 LOG HEADERS33671LogLog Header ScansDF10/13/2020579 343 Electronic Data Set, Filename: KU_42-12_RBT_09JUN20_FreePipe.las34072EDDigital DataDF10/13/20206449 1500 Electronic Data Set, Filename: KU_42-12_RBT_09JUN20_Main.las34072EDDigital DataDF10/13/20206450 6169 Electronic Data Set, Filename: KU_42-12_RBT_09JUN20_Repeat.las34072EDDigital DataDF10/13/2020 Electronic File: KU_42-12_RBT_09JUN20.pdf34072EDDigital DataDF10/13/2020 Electronic File: KU_42-12_RBT_09JUN20_FreePipe.dlis34072EDDigital DataDF10/13/2020 Electronic File: KU_42-12_RBT_09JUN20_img.tiff34072EDDigital DataDF10/13/2020 Electronic File: KU_42-12_RBT_09JUN20_Main.dlis34072EDDigital DataThursday, October 15, 2020AOGCCPage 7 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20689-00-00Well Name/No. KENAI UNIT 42-12Completion Status1-GASCompletion Date6/6/2020Permit to Drill2200450OperatorHilcorp Alaska, LLCMD6521TVD5836Current Status1-GAS10/15/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:6/6/2020Release Date:5/19/2020DF10/13/2020 Electronic File: KU_42-12_RBT_09JUN20_Repeat.dlis34072EDDigital Data0 0 2200450 KENAI UNIT 42-12 LOG HEADERS34072LogLog Header Scans9/10/20201788 65211762CuttingsThursday, October 15, 2020AOGCCPage 8 of 810/15/2020M. Guhl Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/13/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 42-12 (PTD 220-045) RCBL Radial Cement Bond Log GR-CCL 06/09/2020 Please include current contact information if different from above. PTD: 2200450 E-Set: 34072 Received by the AOGCC 10/13/2020 Abby Bell 10/13/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 8/19/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 42-12 (220-045) LWD DATA Please include current contact information if different from above. Received by the AOGCC 08/19/2020 Abby Bell 08/19/2020 PTD: 2200450 E-Set: 33671 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 65' BF: 65' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" X-56 120' 7-5/8" L-80 1,636' 5-1/2" L-80 5,836' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate1056 June 1, 2020 May 24, 2020 FEE A028142, A028143 N/A N/A N/AN/A N/A 6,521' MD / 5,836' TVD ROP, DGR, AGR, ABG, ADR, EWR MD & TVD, GeoTap, CBL 6-9-20 Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 004018 Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A4018 Flowing Liner run on 6/4/20 ** Please see attached schematic for perforation detail ** 0 Water-Bbl: PRODUCTION TEST 7/29/2020 Date of Test: 0 8/1/2020 24 Flow Tubing 0 84# 29.7# 120' 1,636' 6,521' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 17#1,526' DEPTH SET (MD) LTPkr @ 1,636' / 1,526' PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 271051 270777 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 2360167 BOTTOM TOP 6-3/4" 84 bbls Surface 9-7/8" HOLE SIZE AMOUNT PULLED 50-133-20689-00-00 KU 42-12 272070 2362338 1370' FNL, 85' FWL, Sec 7, T4N, R11W, SM, AK CEMENTING RECORD 2360603 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 6/6/2020 284' FSL, 1157' FWL, Sec 6, T4N, R11W, SM, AK 1812' FNL, 180' FEL, Sec 12, T4N, R12W, SM, AK 220-045 / 320-242 / 320-280 Kenai Gas Field / Sterling Undef Gas Pool 82.6' 5,486' MD / 4,820' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas Driven Surface 1,778' L - 203 sx / T - 135 sx Driven L- 200 sx / T - 105 sx 1,639'5-1/2" Tieback Tbg SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 8:39 am, Aug 11, 2020 RBDMS HEW 8/12/2020 Completion Date 6/6/2020 HEW gls 10/19/20 DSR-8/13/2020SFD 8/13/2020 G G Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval ST A7 4,203' 3,580' 4,176' 3,554' 4,220' 3,595' 5,393' 4,730' 5,555' 4,887' 5,752' 5,080' 6,059' 5,382' 6,369' 5,687' Mid Beluga 5 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: UB 3 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports. Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top UB 5A ST A8 Upper Beluga ST A7 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Mid Beluga MB 5 Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 8.10.2020Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.08.10 17:03:10 -08'00' Monty M Myers Updated by DMA 08-10-20 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,486’ MD / TVD = 4,821’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892” 1,636’ 6,521’ 5-1/2” Tieback Tubing 17 L-80 CDC HTQ 4.892” Surf 1,639’ 1/2 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 1,639’ 4.800 6.030 Baker Tieback Assy. 3 5,513’ CIBP w/ 26’ cement – TOC 5,486’ 07/22/20 4 5,820’ CIBP 06/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status A7 4,203’ 4,216’ 3,580' 3,592' 13' 07/29/20 3-3/8” Open UB 3 5,600’ 5,602' 4,932' 4,934' 2' 06/19/20 3-3/8” Isolated UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 3-3/8” Isolated A7 3 4 UB 5B UB 3 + wireline 5600-5602ft (fill in wellbore to 5520 ft... ) TOC @ 1840ft CBL shows excellent cmt from 2250-TD. (gls 10-20-20) fish= 2 ft gun FISH Tieback tubing fill liner hanger Activity Date Ops Summary 5/20/2020 *Changed AFE # @ midnight to well KU 42-12*;Held PTSM, crew change, Cont. R/D & prepping for move to KU 42-12. Disconnected service loop & Kelley hose from TD, installed L/D rigging on TD, set & pinned TD in cradle, L/D TD using new L/D procedure, installed bridal lines on blocks, performed derrick inspection,;R/D TD HPU & hydraulic hoses on rig floor, finished dressing MP #2 w/ 5.5" liners & swabs, removed Handy berm around rig, R/D degasser plumbing in pit #4, R/D shakers & secured w/ load blocks, removed 5000 gal diesel fuel auxiliary tank from rig containment.;R/D stand pipe manifold, suction lines on MP's, over head jumper hoses from pit to pump house, hard line to gas buster, shock hose from pumps to sub, jumper hoses between pit modules. R/D T-bar on TQ tube. Peak cranes will be on location @ 06:00 hrs. R/D lines from choke house.;R/D & move hurricane vac from rig containment, L/D gas buster, folded down derrick board, held PJSM on scoping derrick, current scoping derrick.;Hauled 0 bbls solids to KGFG&I Cumulative 0 bbls Hauled 0 bbls fluid to KGF G&I Cumulative 0 bbls Daily Metal 0 lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 0 bbls 5/21/2020 Continue scoping dn derrick / and r/dn of modules and interconnects of hoses, line and cables / r/dn iron rough neck and dog house / set crane remove wind walls / remove TDS HPU module / work on removing gen #1 for repairs / install shipping blocks in centrifuge /;Lay over derrick / Remove bopes from cellar and install in transport (inspect annular element) cut 24' Drill line / crew change.;Continue work on gen#1 low oil pressure issue / remove iron rough neck / welder work on hit list / remove choke house / install annulus valve on starting head / shuttle equipment to pad 14-6 / remove cmt silo / water tank / boiler / pre-mix module.;Finished disconnecting electrical and HYD lines, blew down H20 lines through out rig, lowered the roof on pit modules, lowered dog house into water tank, disconnected HYD lines from derrick & carrier. Tail rolled pit modules, pumps, boiler, TD HPU, Gen 1&2 building, off to the edge of location.;Spotted cranes, picked & loaded on trucks- derrick from carrier, carrier off sub, & sub off pony subs. Tail rolled pony subs off rig mats, sent rig crew to pad 14-6 to lay felt & liner around KU 42-12, loaded rig mats & hauled to 14-6 pad, finished felt & liner, stated spotting & setting rig mats.;Held PTSM, crew change, Finished setting rig mats, spotted pony subs over KU 42-12, staged trailers around KU 42-12 wellsite, cleaned & folded up liner on KU 24-32 wellsite, picked up sticks & misc. trash around location, pressure washed tree & cellar box on KU 24-32. Set iron roughneck;inside pony subs. Peak rig movers will be on location @ 06:00 hrs. to cont. moving rig to KU 42-12.;Hauled 0 bbls solids to KGFG&I Cumulative 0 bbls Hauled 0 bbls fluid to KGF G&I Cumulative 0 bbls Daily Metal 0 lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 0 bbls 5/22/2020 Trucks, cranes and welder on location continue rig move and weld repairs / move and set sub / set carrier / set derrick / raise dog house / continue move equipment f/ pad 34-31 and stage equipment on pad -14-6 / set gen module / all three pits modules and pumps r/up same.;Continue set in complete rig modules and r/up same / raise derrick / set out buildings / set up wet and dry docks.;Cont. hooking up electrical & water lines, R/U in pits system-jumper lines between modules, degasser, centrifuge, lights, working on shakers, set & plugged in service shacks, inspected derrick, prepped derrick to scope come first light.;Held PTSM, crew change, cont. R/U on KU 42-12, building dry/ wet docks, unloading misc. trailers equip/mud product. Filled rig tank with water & working on filling vertical tank, installed suction lines on pumps, raised gas buster, spooled drilling line on drum, hooked up drilling side wt indicator.;R/U boiler & filling w/ water, R/U catwalk, TD HPU, & hooked up shock hose from pumps to sub. Currently P/U/M/U lower section of TQ tube/ scoping derrick. Cont. working on rig acceptance check list.;Handy berm will be on location this morning to build containment around rig and Peak will be here @ 08:00 hr. to move offices & sleeper to pad 14-6. Total Safety will be here this afternoon to test alarm.;Hauled 0 bbls solids to KGFG&I Cumulative 0 bbls Hauled 0 bbls fluid to KGF G&I Cumulative 0 bbls Daily Metal 0 lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 0 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: KEU KU 42-12 Kenai Gas Field Hilcorp Energy Company Composite Report Kenai, Alaska Contractor AFE #: AFE $: Hilcorp 169 Job Name:2011785D KU 42-12 Drilling Spud Date: *Changed AFE # @ midnight to well KU 42-1 gg R/U on KU 42-1 5/23/2020 Scoped derrick, p/up install TDS / Move complete camp/office trailers from pad 34-31 t/ pad 14-6 and r/up same and establish coms / fire boiler/ install handy berm around rig / take on fuel / receive csg / Transfer water pit to pit repair and chk PVTs and chg out BF valve pit #2.;Total Safety R/up and test gas alarms / r/up mud lab, mud loggers and directional shack/ continue organize location / fill water tank / re-install wind wall behind IR / finish change liners in #1 MP t/ 5- 1/2" / Dress rig floor / install flow nipple and flow line;/ dress shakers / remove shipping blocks on centrifuge / install bleeder off stand pipe and install new saver sub / Continue work on rig acceptance check list.;Built containment for parking vehicles, strap & tally 4.5" DP on rack, racked & removed thread protectors on 7- 5/8" surface casing, hooked up drain hoses from rig floor to cellar, installed 4" valves on conductor & tested (ok), secured conductor to sub, test ESD on all motors, removed test plug;from well, commissioned MP's, had air lines on MP #1 backwards, switched lines around re-tested (ok), attempted to test surface lines, had 4" valve on MP #1 leaking, rebuilt 4" valve, cont. working on rig acceptance check list.;Held PTSM, crew change, cont. working on rig acceptance check list. re-tested surface lines to 4500 psi (ok), installed short mouse hole, brought in 330 bbls of spud mud into pits. Off line strapped, tallied, & drifted 7- 5/8" casing.;Performed rig service, greased crown, blocks, TD, draw works, drive shaft, brake linkage, & iron roughneck.;Checked our TQ against TD, iron roughneck, & tongs. Accepted rig @ 03:00 hrs. P/U wash tool, RIH and tagged 134', currently P/U 4.5" singles off racks and racking it back in derrick.;Hauled 0 bbls solids to KGFG&I Cumulative 0 bbls Hauled 0 bbls fluid to KGF G&I Cumulative 0 bbls Daily Metal 0 lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 0 bbls 5/24/2020 Cont. P/U 4.5" CDS 40 singles & racking back in derrick (total 60 std.),;P/U 17 jt. of 4.5" CDS 40 HWDP & racked back in derrick. Off line production James came out to location and performed VE on boiler.;P/U & M/U 1st stage of 9-7/8" BHA #1 (bit motor, & XO), installed additional weight indicator on ODS.;Drilled F/134'-T/217'. SPP-335 GPM-311 TQ-3-5K WOB-1-4K.;POOH F/217'-T/159' on elevators w/ no issues.;P/U smart tools & remainder of BHA #1, down loaded data, shallow pulse tested, loaded sources, P/U NM flex collars.;Directionally drilled F/217'-T/497'. SPP-1050 psi GPM-420 WOB-3-5K TQ-4.7K.;L/D 1 jt. of HWDP, due to setting down on face of box while making connection (scared face). After further inspection notice nose on saver sub was rolled over & needed changed, made decision to pumped OOH F/497'-T/183'. changed out saver sub same. RIH F/183'-T/497', washing last std. to bottom.;Cont. directionally drilled F/497'-T/640', pumped 20 bbl Hi-Vis w/ walnut & condet, sweep came back on time w/ only a 5% increase in cuttings, cont. drilling ahead F/640'-T/806'. P/U- 44K S/O-44K ROT-44K SPP-1050 psi GPM-420 WOB-5-6K TQ-4.5K on bottom TQ-2.5K off bottom.;Held PTSM/Weekly safety meeting, crew change, Cont. directionally drilled F/806'-T/1372', pumped 20 bbl Hi-Vis sweep w/ walnut & condet, sweep came back on time w/ a 75% increase in cuttings, P/U-50K S/O-45K ROT-47K SPP-1752 psi GPM-510 WOB-2-3K TQ-4.5K on bottom TQ-2.5K off bottom.;Cont. directionally drilled F/1372' to current depth of 1736', P/U-53K S/O- 48K ROT-50K SPP-1727 psi GPM-517 WOB-2-3K TQ-5.5K on bottom. Distance to plan: 14.81' 14.33' High 3.73' Left;Hauled 38 bbls solids to KGFG&I Cumulative 38 bbls Hauled 72 bbls fluid to KGF G&I Cumulative 72 bbls Daily Metal 0 lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 0 bbls 5/25/2020 Cont. directionally drilled F/1736't/ TD @ 1787' MD and 1643' TVD , P/U-56K S/O-48K ROT-50K SPP-1692 psi GPM-518 WOB-2-3K TQ-5.5K on bottom @ 60 rpm.;Circ btm up and pump 20 bbl flagged high vis sweep around back just little early w/ 10% increase in cuttings.;Mad pass slides f/ 1770-t/ 1729' , f/ 346' t/ 311' and 299' t/ 211' and Pump ooh the rest w/ no issues.;L/dn inspect Bha #1 / remove sources and dn load tools / RR bit graded same as it went in @ 1-4- CT-G- X- I-NO-TD.;Service rig / grease traveling equipment / tighten loose hyd fitting on TDS / monitor static hole w/ 3-3-1/2 bph loss rate.;R/up casers / Pull wear ring / dummy run and mark hanger / PJSM.;P/up shoe track & baker lock each jt. checked float equipment (ok) / continue P/U & RIH w/ 7-5/8" 29.70 ppf L- 80 TSH Wedge 563 casing F/128'-T/607', M/U drive sub, circ. BU, GPM-138 SPP-0 P/U-20K S/O-20K MW-8.9 ppg. Losses while circ.=4.9 bbls.;Continue P/U & RIH w/ 7-5/8" 29.70 ppf L-80 TSH Wedge 563 casing F/607''-T/1217', M/U drive sub, circ. BU, GPM-138 SPP-0 P/U-40K S/O-40K MW-8.9 ppg. Losses while circ.=4.4 bbls Gave HES cmt 2 hr. notice.;Continue P/U & RIH w/ 7-5/8" 29.70 ppf L-80 TSH Wedge 563 casing F/1217''-T/1753' , P/U landing jt. & hanger w/ pup, RIH to 1778' (land out depth), P/U-50K S/O-44K MW-8.9 ppg Casing Disp- Cal= 17.28 Act=12.61 Diff=-4.67 bbls.;M/U drive sub & TIW, circ. & conditioned mud, staging pumps up to 5 bpm, GPM-214 SPP-0 P/U-52K S/O-48K GPM-225 SPP-0 MW-8.9 ppg, while R/D Weatherford casing equip & R/U HES cmt. Losses while circ.=5.0 bbls.;Shut down pumps, broke out drive sub & TIW, loaded cmt plugs, M/U cmt head & lines. broke circ. pumped through cmt manifold @ 5 bpm. Gave NOS Sam 2 hr. notice.;Held PTSM, crew change, held PJSM w/ rig hands, HES cmt, Peak, & Baroid, shut down pumps, pumped 5 bbls of water to flush line, pressure tested lines at 910 psi Low & 2800 psi High (ok), HES pumped 40 bbls 10.5 ppg tune spacer @;4 bpm, shut down, dropped bottom plug, pumped 107.8 bbls of 12 ppg Type I II lead cmt @ 5 bpm, followed by 39.7 bbls of 15.8 ppg class G tail cmt @ 3 bpm, dropped top plug, displaced w/ 76.5 bbls of 8.9 ppg spud mud @ 5.3 bpm.;Slowed pump to 3 bpm w/ 60 bbls to go, bumped plug @ 76.5 bbls away. 1.1 bbls early. Cal Disp.=77.6 bbls. Held 1267 psi (FCP of 535 psi) for 3 min, bled off & floats held. Bled back .5 bbl to truck. Had 35 bbls of tune spacer return to;surface & 41.5 bbls of lead Type I II cmt to surface. Added 5.6 ppb of bridge maker LCM to lead cmt and .25 ppb of well life 1094 to tail cmt. Cmt mix water temp 83 deg. Pumped 75% excess open hole. Lost 0 bbls during;cmt job. Did not reciprocate pipe, CIP @ 01:45 hrs. R/D & released HES cmt.;After 1 hr. cmt fell 15' between 7-5/8" casing & conductor, drain remainder of cmt to cellar, flushed conductor w/ black water.;Backed out landing jt. M/U pack off, set pack off, RILD's, tested seal on pack off 500 Low/5000 High 5/5 min (ok). L/D landing jt.;Currently R/D conductor, cleaning pits, & changing MP liners & swabs to 5". Got AOGCC Rep Austin Mcleod on the hook to witness BOP test after P/U 4.5 DP.;Hauled 121 bbls solids to KGFG&I Cumulative 159 bbls Hauled 249 bbls fluid to KGF G&I Cumulative 321 bbls Daily Metal 0 lbs Cumulative Metal 0 lbs Losses to hole 20 bbls Total losses to hole 20 bbls cement surf casing 75/8" pp Lost 0 bbls during;cmt job. g pppp HES pumped 40 bbls 10.5 ppg tune spacer @;4 bpm, shut down, dropped rpppg()ppppgp@p pp bottom plug, pumped 107.8 bbls of 12 ppg Type I II lead cmt @ 5 bpm, followed by 39.7 bbls of 15.8 ppg class G tail cmt @ 3 bpm, dropped top plug, displaced p g p p ppg yp @ p y ppg @ p pp p p g p w/ 76.5 bbls of 8.9 ppg spud mud @ 5.3 bpm.;Slowed pump to 3 bpm w/ 60 bbls to go, bumped plug @ 76.5 bbls away. 1.1 bbls early. Cal Disp.=77.6 bbls.ppg p @ p p p p g p p g @ y y p Held 1267 psi (FCP of 535 psi) for 3 min, bled off & floats held. Bled back .5 bbl to truck. Had 35 bbls of tune spacer return to;surface & 41.5 bbls of lead Type Ip( II cmt to surface. A , RIH and tagged 134', gg RIH w/ 7-5/8" 29.70 ppf L-80 TSH Wedge 563 casing F/607''-T/1217', x collars.;Directionally drilled F/217'-T/497'. SPP-1050 Spud Well 5/26/2020 Nip/up Cactus 11" x 13" "B" section of well head as per well head hand and test 500L 5/min and 5000H 15/min both good / r/up choke line r/dn moving beams / cleaning pits working on 2nd batch of PHPA mud system / chg liners in MP's t/ 5".;spot crane / spot bope carrier / hang and trolley bopes nip/up same / spot geo span in cellar and r/up same / pressure up koomey.;Function test and Installed test jt and test plug preform shell test t/ 3500 psi, L/D Test equipment, set wear ring.;P/U 4.5'' DP RIH 46 jts stand back in derrick, P/U RIH w/ 24 jts DP.;Pull Wear ring R/U to test BOP's w/ state inspector Austin Mcleod, Total Safety tested gas alarms.;Test BOP's as per regulations w/ 4.5'' test jt t/ 250/3500 psi state inspector Austin Mcleod witnessed test,;R/D Test Equipment, Blow down lines, set wear ring, Load walk and P/U BHA components, R/U handling equipment on rig floor.;R/U and Test Casing t/ 2500 psi f/ 30 min, good test 1.8 bbls pumped .7 bbls bled back.;P/U BHA #2 Drilling assembly as per DD/MWD, change bend on motor f/ 2.12 to 1.5.;Hauled 3 bbls solids to KGFG&I Cumulative 162 bbls Hauled 487 bbls fluid to KGF G&I Cumulative 808 bbls Daily Metal 0 lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 20 bbls 5/27/2020 Continue P/U BHA #2 Drilling assembly as per DD/MWD, wash dn tag cmt plugs @ 1685' drill same t/ float collar on depth @ 1691.5' continue drill cmt and shoe @ 1776 and cmt and formation t/ 1789'.;Pump spacer and displace hole t/ 9.1 ppg 6% KCL PHPA mud / clean spud mud out of short system while drilling f/ 1789' t/ 1807'.;Circ clean chk MW @ 9.1 ppg.;Preform F.I.T t/ 13.8 ppg EMW w/ 406 psi applied pressure @ 1643' TVD w/ 10.3 gal pumped and 4.6 gal back (See charts) Blow dn line and line up valves.;Dir drill 6-3/4" hole f/ 1807' t/ 2495' 263 gpm 1430 psi 80 rpm 5k tq on 3.8k tq off 9.1 ppg MW 10 ppg ECD, 54k PUW 44k SOW 48k ROT.;Drill Ahead f/ 2495' t/ 2805' 274 gpm 1580 psi 80 rpm 4.7k tq on 3.8k tq off MW 9.1 ppg ECD 9.85 ppg , PUW 60k SOW 49k ROT 54k Distance to plan 5.24' 3.88' high 5.52' Left.;Circulate bottoms up, SPR's, shoot survey.;POOH f/ 2805' t/ 1749' No Hole Issues Calc 7.1 bbl Act 7.2 bbls.;Service Rig and Top Drive, monitor well f/ 30 min well static.;RIH f/ 1749' t/ 2805' No hole issues Actual 20.6 bbls Calculated 21 bbls.;Hauled 55 bbls solids to KGFG&I Cumulative 217 bbls Hauled 275 bbls fluid to KGF G&I Cumulative 1083 bbls Daily Metal 7 lbs Cumulative Metal 7 lbs Losses to hole 0 bbls Total losses to hole 20 bbls Annulus 0 psi 5/28/2020 Establish SPR / load pipe w/ 20 bbl high vis sweep / Resume Drilling 6-3/4" dir hole f/ 2805' t/3303' 274 gpm 1638 psi 80 rpm 6.2k tq on 5.9k tq off MW 9.1 ppg ECD 9.85 ppg , PUW 62k SOW 54k ROT 46k sweep back on time w/ 10% increase w/ 26 units gas.;Load pipe w/ 20 bbl high-vis sweep / Continue Drilling 6-3/4" dir hole f/ 3303' t/3799' 274 gpm 1638psi 80 rpm 6.2k tq on 5.9k tq off MW 9.1 ppg ECD 9.85 ppg , PUW 62k SOW 54k ROT 46k sweep back on time w/ 10% increase w/ 34 units gas.;Circulate bottoms up, Obtain SPR's pump up Survey f/ MWD.;Make wiper Trip f/ 3799' t/ 2867' No Hole Issues Calculated 6.3 bbls Actual 8.59 bbls.;Service Rig and Top Drive, Observe well static.;RIH f/ 2867' T/ 3799' No Hole Issues no fill Calculated 17.2bbls Actual 16.2 bbls.;Pump Sweep, Drill Ahead f/ 3799' t/ 4540' 274 gpm 1600 psi 80 rpm 7.2k tq on 6.8k off 9.05 ppg MW 9.98ppg ECD PUW 79k SOW 57k ROT 64k Sweep brought back 50% increase in cuttings Distance to plan 14.33' 9.81' low 10.45' left.;Hauled 75 bbls solids to KGFG&I Cumulative 292 bbls Hauled 175 bbls fluid to KGF G&I Cumulative 1258 bbls Daily Metal 1 lbs Cumulative Metal 8 lbs Losses to hole 0 bbls Total losses to hole 20 bbls Annulus 0 psi 5/29/2020 Continue Directional Drill 6-3/4" hole f/ 4540' t/ 5099' @ 271 gpm 1600 psi 80 rpm 10.3k tq on 8.4k off 9.50 ppg MW 9.98ppg ECD PUW 99k SOW 59k ROT 72k.;Continue Directional Drill 6-3/4" hole f/ 5099' t/ 5160' Started taking losses @ 5154'. 8 bbl initial loss static just slight seepage.;Reduced pump rate and controlled drilled f/5160' t/ 5343' w/ 165 gpm and SPP@ 950 psi in attempt to drill through zone w/ manageable losses @ 5333' lost returns but held full column of mud w/ 260 gpm.;Pump 23.7 bbl 30 PPB LCM pill and displace out of bit and top fill w/ 72 bph loss rate build 2nd pill rack back 4 std get above complete loss zone Pump 2nd 23 bbl 30PPB LCM pill and dis place out of bit @ 5077'.;Pooh f/ 5073' t/ 4640'.;Monitor loss rate on trip tank while building mud volume w/ initial losses @ 36 bph maintained loss rate, Transfer 350 bbls f/ pre mix to active, Build 40 ppb LCM pill.;Pump 20 bbl LCM pill at idle slight returns through out pumping, spot outside the pipe and monitor loss rate and let pill soak.;Monitor loss rate on trip tank Initial loss rate 24.6 bph loss rate, Stabilize after 10 min continue monitoring well no losses, continue building volume.;POOH on trip tank f/ 4640' t/ 3639' No hole issues Calculated 7.1 bbls actual 9 bbls.;Monitor well f/ 10 min slight loss, Establish circulation 114 gpm 550 psi no losses, stage pumps t/ 165 psi 790 psi slight to no losses170 gpm 820 psi no losses.;RIH slowly f/ 3639' t/ 5091' No Hole Issues Took correct displacement.;Hauled 40 bbls solids to KGFG&I Cumulative 332 bbls Hauled 135 bbls fluid to KGF G&I Cumulative 1393 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 524 bbls Total losses to hole 544 bbls Annulus 0 psi FIT = 13.8ppg jjgp ;Test BOP's as per regulations w/ 4.5'' test jt t/ 250/3500 psi state inspector Austin Mcleod witnessed test,;R MIT 7 5/8" to 2500 psi q Test Casing t/ 2500 psi f/ 30 min, / Resume Drilling 6-3/4" dir hole f/ 2805' t/3303' 274 gpm p p p ppg p y ppg.;Preform F.I.T t/ 13.8 ppg EMW w/ 406 psi applied pressure @ 1643' TVD w/ 10.3 gal pumped Nip/up Cactus 11" x 13" "B" section of well head Drill 6-3/4" hole f/ 4540' t/ 5099' 5/30/2020 Establish circulation @ 5091' just above loss zone / stage up rate 114 gpm 550 psi no losses, stage pumps t/ 165 psi 790 psi slight to no losses170 gpm 820 psi no losses.;Continue rih f/ 5091 t/ 5346' wash and ream last stand to btm @ 114 gpm 501 psi.;Encounter complete losses w/ hole standing full w/ pump on any rate / drill stand down at minimal rate 114 gpm 501 psi f/ 5346' t/ 5407' w/ no returns attempt to take survey X2 w/ no luck up 110k / dn 69k / rot 83k / 913 psi at 160 gpm / 9.8k TQ on.;Circ and spot 20 bbl 40 ppb LCM pill around corner on btm.;Pooh f/ 5407' above pill t/ 4719' CAL. = 4.2 bbls / ACT= 28.4 bbls /DIFF = 24.2 bbls up/wt 95k dn/wt 65k.;Monitor static hole @ avg 37.9 bph while building LCM pill.;Pump and spot a 21 bbls 40 ppb LCM pill @ 4719' @ 419 psi @ 111 gpm.;Continue pooh f/ 4713' t/ 700' calculated 34.6 bbls actual 97.6 bbls.;Stand Back BHA, Unload sources, L/D BHA as per DD/MWD Clean and clear floor.;M/U mule shoe RIH t/ 5143' Calculated 36.8 bbls Actual 56.7 bbls.;Spot in cementers and R/U t/ pump 20 b bls cement, M/U Cement head and lines Monitor well on trip tank static loss rate 30 bph, PJSM.;Pump 5 bbls water ahead, PT Lines t/ 700/3180 psi, Batch up & Pump 20 bbls of 15.8 ppg cement w/ 2 ppb well barrier @ 2 bpm cement wet @ 0220 hrs, shut down displace w/ Rig 70.45 bbls 9 ppg drilling mud, no returns through out most of job got partial returns 64 bbls into displacement.;POOH f/ 5143' t/ 4527' calculated 4.2 bbls Actual 6.4 bbls.;Drop wiper balls stage pumps up t/ 205 gpm 112 psi 40 rpm 5.4k tq work pipe with rotary slight losses observed while pumping. Flow check well f/ 10 min.;POOH f/ 4527' t/ 2340' No Hole Issues.;Hauled 0 bbls solids to KGFG&I Cumulative 332 bbls Hauled 0 bbls fluid to KGF G&I Cumulative 1393 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 820 bbls Total losses to hole 1364 bbls Annulus 0 psi 5/31/2020 Continue POOH f/ 1964'' t/Bha #3 w/ No Hole Issues.;L/dn bha# 3 / clear clean rig floor / monitor well static while servicing rig.;P/up Bha # 4 dumb iron clean out assy for 6-3/4" hole.;Rih t/ shoe @ 1769' fill pipe and circ btm up warm mud @ 172 gpm / continue RIOH w/ no issues / Fill pipe circ btm up @ 3443' @ 170 gpm / RIOH t/ 4979' and wash dn @ minimal rate 114 gpm t/ tag @ 5272'.;Establish parameters c/out cmt @ 114 gpm @ 178 psi / 78 rpm 1-5k wob and 8.5k torque drill cmt f/ 5272' t/ 5407' w/ no losses observed.;Drill 6-3/4" hole and stage rate t/ 195 gpm f/ 5407' t/ 5429' w/ no losses observed / P/U 110k / S/O 64k / ROT/ 78k TQ 9.5k.;Circ btm up @ 183 gpm @ 177 psi.;Pooh f/ 5429' t/ Surface L/D Clean Out Assy.;M/U Drilling Assembly BHA #5 t/ 700' Shallow test tools load sources RIH t/ 1627'.;Slip and cut drilling line, service rig and top drive no losses during monitoring.;RIH f/ 1627' t/ 5409' No Hole Issues.;Establish parameters, Wash to bottom @ 5429' 180 gpm 895 psi 60 rpm 11k, attempt t/ mode switch MWD, change choke in Geo Span unit, retry mode switch.;Hauled 5 bbls solids to KGFG&I Cumulative 337 bbls Hauled 95 bbls fluid to KGF G&I Cumulative 1488 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 170 bbls Total losses to hole 1534 bbls Annulus 0 psi 6/1/2020 Directional drill 6-3/4" hole f/5429' t/ 5625' at reduced ROP and work through bad detection issues re-chk MP suction and discharge screens / test geo span ok/ bleed MP # 2 pulsation Dampener dn to 300 psi w/ slides as necessary to maintain wp06.;Continue drill ahead f/ 5625' t/5806' w/ slides as necessary to maintain wp06 and minimal losses observed up/wt 93k, dn/wt 57k, rot/wt 68k 180 gpm @ 1052 SPP , TQ 11.0k on & 10.7k off @ 80 rpm w/ 2.5k WOB.;Continue Drilling 6 3/4'' Hole f/ 5806' t/ 6337' 180 gpm 1330 psi 80 rpm 12k to on 11k tq off 9.05ppg MW ECD 10.1ppg PUW 103k SOW 59k Rot 73k.;Continue Drilling Ahead f/ 6337' t/ 6521' 180 gpm 1214 psi 80 rpm 11.9k tq on 11.5k off 9.05 ppg MW, 10.06 ppg ECD Distance to plan 30.05' 29.84' High 3.60' Right.;Circulate bottoms up x 2 until shakers clean up 180 gpm 1200 psi 80 rpm, downlink MWD tools, Obtain SPR's.;POOH f/ 6521' Madd Passing and Geo Tapping as per DD/MWD and Geo Over pulling 40k to break over after first two stations. Pulling up to next station @ 6272'.;Hauled 30 bbls solids to KGFG&I Cumulative 367 bbls Hauled 120 bbls fluid to KGF G&I Cumulative 1608 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 170 bbls Total losses to hole 1534 bbls Annulus 0 psi 6/2/2020 Cont working up hole mad passing and Geo Tapping from 6272’ to 5641'. Obtained 6 stations with good results. Peak super sucker vacuum pump had a failed seal. Spilled 1/8 cup hyd fluid to gravel ramp. Cleaned up same and notified Hilcorp HSE Rep.;Cont working up hole mad passing and Geo Tapping from 5641' to 4532'. Obtained 10 stations with good results. While sampling, 183 gpm-887 psi. Hole still taking 2-3 bph with 9.1 ppg. Received Baker cement head, liner hanger/packer, seal assembly, landing collar and tool basket.;Cont working up hole mad passing and Geo Tapping from 4532' to 4149'183 gpm 850 psi hole taking 2-3 bph.;POOH f/ 4149'' t/ 700' Stand back HWDP and Jars, L/D BHA L/D sources, L/D remaining BHA as per DD/MWD, Break Bit clear floor.;Service Rig and Top Drive.;M/U Clean Out Assembly Bit, Bit Sub and Stab RIH, P/U HWDP from Rack 12 jts.;Hauled 18 bbls solids to KGFG&I Cumulative 385 bbls Hauled 112 bbls fluid to KGF G&I Cumulative 1720 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 60 bbls Total losses to hole 1594 bbls Annulus 0 psi 6/3/2020 MU 6 ¾” roller cone bit, bit sub and stab, TIH 5 jnts HWDP, jars, 11 jnts HWDP, then PU 12 more jnts HWDP. Cont TIH slow, stopping at shoe to fill pipe, then every 2000’. Tagged up at 6450’, MU topdrive and washed/reamed to bottom at 6521'. Up wt 92K, dwn wt 56K.;Pumped 20 bbl LCM sweep around 181 gpm-374 psi, 80 rpm-12,800 to 14,200 ft/lbs off bott torque. Sweep came back on time, no increase in cuttings, max gas 59 units. Added 1 drum NXS lube to suction pit and spotted same outside drill string.;Dropped hollow 2.43" drift with wire, POOH on elevators from 6521' to 3349', up wt 92K. At 3349', flow check = slight seepage, RU vac hose and ball catcher, began LD of 4 1/2" DP.;POOH L/D DP f/ 3349' t/ 904' L/D 4.5 '' DP Vacuuming Balls through pipe to clean out mud.;POOH Standing Back HWDP and L/D BHA components.;R/U and Pull wear ring and test plug, Change rams t/ 5.5'' Solid body rams, R/U t/ test.;Test upper rams and annular t/ 250/3500 psi R/D test equipment, Set wear ring.;R/U Weatherford and run 5.5'' Casing.;PJSM RIH w/ 5.5'' Liner 17# L-80 CDC HTQ torqueing t/ 10000 ft/lbs, Check floats held, continue RIH filling on the fly topping off every 10 jts. ;Spot in cementers and R/U t/ pump 20 b bls cement, gp p p pg gp ;Encounter complete losses w/ hole standing full w/ pump onp@gp p p gpp any rate / drill stand down at minimal rate 114 gpm 501 psi f/ 5346' t/ 5407' w/ no returns attempt to take survey X2 w/ no luck up 110k / dn 69k / rot 83k / y 913 psi at 160 gpm / LCM pill Geo Tapping from 6272’ to 5641'. 20 bbls cement gp g @ p @ gp observed.;Drill 6-3/4" hole and stage rate t/ 195 gpm f/ 5407' t/ 5429' w/ TD well g gpp Change rams t/ 5.5'' Solid body rams, R/U t/ test.;Test gpgpgg upper rams and annular t/ 250/3500 psi R/D test equipment, Set wear ring.;R/U Weatherford and run 5.5'' Casing.;P g 73k.;Continue Drilling Ahead f/ 6337' t/ 6521' Continue POOH f/ 1964'' t/Bha #3 w/ No Hole Issues.; ;Circ and spot 20 bbl 40 ppb LCM pill around corner on btm. gp p Test rams... RIH with 5 1/2" casing 6/4/2020 Cont PU single in hole with 5 1/2" liner from 400’ to 1761’, just above the surface shoe, MU circ swedge and topdrive.;Circulated at 173 gpm-82 to 72 psi, staged Baker cement head on catwalk. Baker Rep installed wiper dart, rig crew installed XO's and 5' pup jnt on top of head. Up wt 25K, dwn wt 25K, rot wt 25K 10=1770 ft/lbs, 20=2210 ft/lbs, 30=2350 ft/lbs.;Cont to PU and ease in hole with liner from 1761' to 4849’, getting decent displacement. At 4849’ C/O elevators, PU and MU liner hanger assembly, mixed and poured “Xanplex”, MU 1st stand HWDP and eased down to 4947’. MU topdrive. Up wt 63K, dwn wt 36K. RD Weatherford casing equip.;Circulated slow, pump at idle, 2.7 bpm-220 psi with good returns initially. Pump pressure and return flow cont to drop off as we did bottoms up, to the point nothing on flow show (slight returns), pressure stable at 109 psi. 10 rpm=7400 ft/lbs, 20 rpm=8300 ft/lbs, 30 rpm=9000 ft/lbs.;Cont to TIH at 20 ft/minute with 14 stands HWDP then 13 stands DP. Tagged up at 6481', MU topdrive and washed down to bottom at 6521' with no issue.;LD top single of DP stand #13, PU and MU Baker cement head, MU topdrive and torqued through head. MU low torque valve on head (closed) and resumed circ while RU manifold, wash up hose, hardline to floor and chicksans to cement head. Circ at 114 gpm-524 psi, no losses.;Held PJSM with cementers, Baker Rep, Peak drivers and rig team.;Halliburton pumped 3 bbls water to flush lines, then 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 830 psi low 4900 psi high. Good tests. Lined up Baker cement head to Halliburton, pumped 40 bbls 10.5 ppg Tuned Prime Spacer at 4 bpm- 1080 psi, followed with 83 bbls (200 sx) 12.0;ppg Type 2 Lead cement at 4 bpm, to 500 psi, followed with 23 bbls (105 sx) 15.3 ppg Premium Tail cement at 2 bpm, 121 psi. Had 5 ppb Bridge master LCM in lead, 3 ppg in tail. Baker released dart, Halliburton then displaced with 9.1 ppg 6% KCL mud at 2 bpm- 27 psi ICP. Saw dart latch wiper plug @;16.8 bbls pumped bumped liner wiper plug/landing collar at 126.4 bbls into displacement (calculated at 127.8 bbls). FCP 1540 psi. Halliburton in creased to and held 2500 psi (960 over fcp) for 5 minutes. Bled back 1.75 bbls to truck and floats held. Slacked off on blocks from 88K to 26K, giving us a;good indication hanger was set. CIP at 23:00 on 6-4-18. Initially rotated at 10 rpm-12,200 to 13,156 ft/lbs off bottom torque, up wt went from 90K to 103K so stopped rotating and reciprocating.;Lost all returns after spacer was pumped, pumped remaining cement and displacement @ 2 bpm turned on hole fill to keep hole full while pumping cement, 40 bbls into displacement returns came back maintained full returns throughout remainder of job total loss to hole 151 bbls.;PU 8.5' with good indication we released from liner string, lined up and reverse circulated at 143 gpm-100 psi. Had 40 bbls spacer and 20 bbls cement/contaminated mud at the shakers. Shut down pump.;S/O to 18K to set packer with rotation, good indication of shear. Top of liner hanger at 1639.01’, top of landing collar at 6436’. Shut down pump, broke off top drive, LD cement head and single joint, installed wiper ball in drill string, MU top drive and pumped citric sweep ahead of second;circulation at 253 gpm-54 psi. RD and released Halliburton cementers.;POOH L/D Liner HRDE run tool, Dog Sub Sheared, P/U Cement head broke down 5' pup and XO's.;R/U and test liner top packer and casing t/ 2500 psi f/ 30 min on chart, good test, blow down lines and RD test equipment.;M/U Polish Bore Clean Out Assembly with Baker Rep, RIH on HWDP t/ 420'. Start cleaning pits and flushing surface lines for building brine.;Hauled 20 bbls solids to KGFG&I Cumulative 411 bbls Hauled 85 bbls fluid to KGF G&I Cumulative 1899 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 232 bbls Total losses to hole 1868 bbls Annulus 0 psi 6/5/2020 Cont TIH with Baker polish mill from 420' to 1622'. Circ at 260 gpm-90 psi, 18 rpm-2204 ft/lbs off bott torque. Worked down into sealbore receptacle tagging no- go up on liner top at 1639'. Repeat one time as per Baker Rep and shut down.;POOH from 1636' to surface, LD Baker polish mill. Mill in good condition.;Drained BOP stack, pulled wear ring, set test plug with 2 7/8" test joint. RU test equipment/chart recorder, tested lower rams and annular at 250/3500 for 5 min each on 2 7/8” test jnt, tally 2 7/8” work string. RD test equipment and test plug, set wear ring.;RU Weatherford handling equipment and tongs. Held PJSM.;MU 4 3/4" rollercone bit and scraper assembly, PU single in hole with 2 7/8” PH-6 work string to 3716', no issue entering liner top at +/- 1636’. RD and released GeoLog shack and mud loggers, RD and released Sperry shack and MWD Rep, loaded and shipped Sperry tools. Received new;drill line spool. Swaco Rep installed shipping blocks in centrifuge. Built 6% KCL brine for upcoming displacement. Shipped out 3 trailers of mud products. Shipped SLB jars and Baker polish mill, cement head, rotating dog sub and liner hanger run tool.;Cont PU single in hole with PH-6 work string from 3716' to 4931', MU XO to CDS-40, cont TIH with HWDP and DP t/ 6437' tag up on LC.;Break circulation 141 gpm 400 psi attempt to wash down not making hole, turn rotary on 20 rpm 4.5k tq not making hole, turn up pump rate t/ 140 gpm 690 psi, Displace well t/ 8.75 ppg brine, clean up shakers.;POOH L/ D 4.5'' DP RIH w/ 22 stands of DP, POOH L/D DP t/ 2 7/8'' RIH w/ remaining DP f/ Derrick, POOH L/D all remaining DP.;Hauled 14 bbls solids to KGFG&I Cumulative 425 bbls Hauled 1162 bbls fluid to KGF G&I Cumulative 3061 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 0 bbls Total losses to hole 1868 bbls Annulus 0 psi 6/6/2020 Cont POOH from 5434' to 4939', LD last of 4 1/2" DP and XO. RU Weatherford tongs and 2 7/8" handling equipment, held PJSM, POOH LD 2 7/8" workstring, XO’s, scraper and bit, all in good shape.;Pulled wear ring and dummy ran hanger. C/O handling equipment to 5 1/2". Stage seal assembly and 5 1/2" tubing on racks. Held PJSM. Drained glycol and oil from gen #1, shipped DP, HWDP and 2 7/8" workstring to Tuboscope, shipped load of rig mats to Peak yard, shipped load of mud products.;PU and MU Baker 5.5" Bullet Tie-Back Seal Assembly (3 x 5.75" seal OD) with half mule shoe on first joint. Cont PU single in hole total 40 joints 5 1/2" 17# L-80 CDC HTQ tubing. Land "no-go" on liner top at 1636'. Space out and MU hanger and pup jnt. Land hanger, up wt 30K, down wt 28K.;Back out landing joint from hanger, pulled to floor, installed packoff assembly, landed packoff assembly on hanger, RILD's.;RU and tested 5 1/2" tubing and liner at 2500 psi f/30 min on chart, pumped 95.5 gals, bled back 98 gals. Tested OA at 2500 psi f/30 min on chart, pumped 20.7 gals, bled back 17.5 gals. RD test equipment and wellhead Rep installed BPV.;Flushed through pumps, pit plumbing, mud lines, topdrive and choke manifold with Baraclean and blew everything down.;Removed flow line and riser, removed drip pan, installed I beam for trolley, RU and removed annular cap, removed old annular element, cleaned out annular and installed new element, installed cap and torqued bolts.;Changed out upper rams to 2 7/8'' x 5'' variables, shut doors and tightened, N/D choke and kill lines, bled off and removed Koomey lines, broke bolts on stack and racked back out of the way on trolley.;N/U dry hole tree and adaptor flange, tightened bolts, installed tree cap, tested packoff neck seals at 500 psi f/5 min, 5000 psi f/5 min. Tested void at 500 f/5 min, 5000 psi for 15 min. Pulled BPV, set 2 way check, tested dry hole tree at 5000 psi f/5 min. Pulled 2 way check. Installed tree cap;with gauge. SIMOPS: cont cleaning up in pits, start RD of poorboy degasser, break jumper hoses, prep to start tear out of back yard items. Rig Released at 06:00 on 6-7-20.;Hauled 8 bbls solids to KGFG&I Cumulative 433 bbls Hauled 192 bbls fluid to KGF G&I Cumulative 3253 bbls Daily Metal 0 lbs Cumulative Metal 8 lbs Losses to hole 0 bbls Total losses to hole 1868 bbls Annulus 0 psi run 5 1/2 " tieback yyyypgg installed tree cap, tested packoff neck seals at 500 psi f/5 min, 5000 psi f/5 min. Tested void at 500 f/5 min, 5000 psi for 15 min. Pulled BPV, set 2 way pp p p check, tested dry hole tree at 5000 psi f/5 min. Pulled 2 way check. Installed MIT T - 2500 psi MIT-IA - 2500 psi ppj p 4931', MU XO to CDS-40, cont TIH withgg g g g HWDP and DP t/ 6437' tag up on LC.;Break circulation 141 gpm 400 psi attempt to wash down not making hole, turn rotary on 20 rpm 4.5k tq not making hole, gp turn up pump rate t/ 140 gpm 690 psi, Displace well t/ 8.75 pp p p MU topdrive and washed down to bottom at 6521' with no issue. Tested OA at 2500 psi f/30 min on chart, p ppg Shut in at Baker cement head and PT lines at 830 psi low 4900 psi high. Good tests. pp ppg Lined up Baker cement head to Halliburton, pumped 40 bbls 10.5 ppg Tuned Prime Spacer at 4 bpm- 1080 psi, followed with 83 bbls (200 sx) 12.0;ppg Type 2pppppgppp()ppgyp Lead cement at 4 bpm, to 500 psi, followed with 23 bbls (105 sx) 15.3 ppg Premium Tail cement at 2 bpm, 121 psi. Had 5 ppb Bridge master LCM in lead, 3 p p ( ) ppg p p pp g ppg in tail. Baker released dart, Halliburton then displaced with 9.1 ppg 6% KCL mud at 2 bpm- 27 psi ICP. Saw dart latch wiper plug @;16.8 bbls pumped rppg p ppg p p p pg@ p p bumped liner wiper plug/landing collar at 126.4 bbls into displacement (calculated at 127.8 bbls). FCP 1540 psi. Halliburton increased to and held 2500 psi (960 pppgg p( ) p p( over fcp) for 5 minutes. Bled back 1.75 bbls to truck and floats held. Slacked off on blocks from 88K to 26K, giving us a;good indication hanger was set. CIP at p)gg g g 23:00 on 6-4-18. Initially rotated at 10 rpm-12,200 to 13,156 ft/lbs off bottom torque, up wt went from 90K to 103K so stopped rotating and reciprocating.;Lost allyp qp ppgpg returns after spacer was pumped, pumped remaining cement and displacement @ 2 bpm turned on hole fill to keep hole full while pumping cement, 40 bbls into ppppp g p@p p ppg displacement returns came back maintained full returns throughout remainder of job total loss to hole 151 bbls.;PU 8.5' with good indication we released frompgjg liner string, lined up and reverse circulated at 143 gpm-100 psi. Had 40 bbls spacer and 20 bbls cement/contaminated mud at the shakers. Shut down gp gpp p pump.;S/O to 18K to set packer with rotation, good indication of shear. Top of liner hanger at 1639.01’, top of landing collar at 6436’ g ypp Cont PU single in hole total 40 py()jg joints 5 1/2" 17# L-80 CDC HTQ tubing. Land "no-go" on liner top at 1636'. Space out and MU hanger and pup jnt. Land hanger, up wt 30K, down wt 28K.;Back jggppgppjgp out landing joint from hanger, pulled to floor, installed packoff assembly, landed packoff assembly on hanger, RILD's.;RU and tested 5 1/2" tubing and liner at yp yggj 2500 psi f/30 min on cement 5 1/2" liner Cont TIH with Baker polish mill from 420' to 1622'. Circ Activity Date Ops Summary 6/9/2020 Sign in. PTW and JSA. Spot equipment and rig up lubricator.,RIH w/Halliburton CBL tool at 50 fpm and tag at 6436'. Logged up from 6436' to 1500' at 50 fpm. Found TOC at 1874'. Send field copies to town.,Rig down equipment and helped wellhead man put the tree on with Halliburton cran e. 6/13/2020 Review activity scope, discuss risks, sign permit to work,Spot coil equipment, crane, and RU. Function test BOP rams.,Pressure test coil BOPE to 4000 psi high/250 psi low. State witness waived by Jim Regg,Finish rigging up equipment. Flange up BOP's on top of well with night cap installed. Depart location. 6/14/2020 Hold PJSM, review and sign permits,MU coil lubricator, injector and PT to 4000 psi.,RIH with 2.20" big hole nozzle while circulating N2 down coil, taking returns to surface tank.,Recovered 100 bbls of wellbore fluid. Stop pumping N2 down coil, start pumping N2 down coil x tubing annulus while taking returns up coil.,RIH and tag PBTD at 6432' ctmd. Recover a total of 164 bbls of wellbore fluid. POOH with coil and leave 1400 psi of wellhead pressure. Shut in well.,RDMO 6/16/2020 Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3500 psi high. TP - 1430 psi,RIH w/3-3/8"x10' HC (Razor), 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Bled tubing down to 1005 psi while going in hole. Get ok to perforate from 5853' to 5863' with 1005' psi on tubing. Spot and fire gun. After 5 min - 1007 psi, 10 min - 1006 psi, 15 min - 1004 psi and 20 min - 1002 psi. POOH. All shots fired and gun was dry.,Rig down lubricator and turn well over to field. 6/18/2020 Review JSA and PTW,MIRU lubricator and MU water hold up toolstring. Confirm fluid level at 4572' md.,Attempt to recover water sample using sample bailer. Unsuccessful in two attempts, suspect ball is not holding seal on seat while passing through deviated section of wellbore.,RIH with water hold up toolstring, while pumping Nitrogen to bullhead water into formation. Confirm water was displaced to bottom of perf interval at 5863' md.,RIH and set 5-1/2" Geo CIBP at 5820' mid element.,RIH with 3-3/8" razor perf gun 4' in length. 6 spf, 60 deg phasing. Correlate on depth. Bleed surface pressure down to 251 psi. Perforate 5760 - 5764'. 5 minute pressure = 251 psi, 10 minute pressure = 250 psi, 15 minute pressure = 250 psi. Perf gun at surface, all shots fired.,Laydown perf gun and equipment for the night. 6/19/2020 PTW and JSA. Spot equipment and rig up Lubricator. PT to 250 psi low and 3500 psi high.,RIH w/GPT and went down to 5700' and found no fluid. POOH,RIH w/3- 3/8"x2' HC Razor, 6 spf, 60 deg phase perf gun and tie into CBL log. Ran correlation log and send to town. Told to add 2' to our log. Added 2' and spotted gun from 5600' to 5602' with 113 psi on tubing. Fired gun and lost 700 lbs of line tension right away. Picked up to 5446' (btm of gun) and was stuck. Worked tools from 1600 lbs up to 3000 lbs in 100 lb increments and tools popped free. Pull up to 452' and kinked,line would not go thru grease tubes. Started cutting and slipping line thru grease head. well was blowing tools up hole every time we slipped and cut wireline. All of a sudden line parted with the tools on the end. Pulled rest of line out of lubricator. We estimated about 150' of 5/16" e-line and 16.5' of tools. Got tool drawing to Pollard slickline and they will be here at 7 am.,Rig down lubricator and crane. Secure well and turn well over to field. 6/20/2020 ARRIVE AT KGF DO PERMIT AND JSA- START AND WARM EQUIPMENT AND MOVE TO LOCATION- MEET WITH BILLY RIG UP SLICKLINE .160 WIRE MAKE UP 7" LUB AND WLV WITH ADDITIONAL 4" LUB P/T LUB 2500 PSI GOOD,RIH/W 4 1/2" GR /W BAIT SUB/W X/O /W INLINE 4.5" WIREFINDER/W 1.75" DD BAILER (OAL 77" FROM BAIT SUB TOP) TO NEG 5' SLM ( 13' RKB) CAN NOT PASS THRU THE TREE W/T BY HAND POOH TO CHECK TOOLS CLOSE BTM MASTER TO LOOK DOWN TREE CLEAR CHECK TOOLS LOOK OK,RIH/W SAME TO 5129' SLM ( 5137' RKB) W/T 5138' SLM ( 5146' RKB) 400 LBS OVERPULL POOH TO CHECK TOOLS OOH MARKS ON WIREFINDER AND BAILER BTM RIH/W 4.5" LIB TO 5130' SLM 5148' RKB W/T POOH 4050' SLM LIGHT OVERPULL ON POOH OOH IMP OF ELINE RIH/W 4 1/2" GR /W BAIT SUB/W XO/ W INLINE 4.5" WIREFINDER /W CENTER SPEAR (OAL 71") TO 5130' SLM ( 5148' RKB) W/T POOH WITH OVERPULL OOH WITH 12' ELINE,RIH/W SAME TO 5146' SLM ( 5164' RKB) W/T GET A COUPLE HUNDRED LBS OVERPULL- POOH OOH CAN NOT SHUT VALVES DUE TO LINE ACROSS THEM- SHUT IN WLV AND START BLEEDING OFF UPPER LUB START STRIPPING WIRE FROM DOWNHOLE RECOVER 45' RIH/W SAME TO 5575' SLM ( 5593' RKB) W/T TO 5578' SLM (5596' RKB) W/T UP TO 1600 LBS ONE TIME (P/U WEIGHT WAS 500) COME FREE WITH 1200 ON GAUGE PULL TO SURACE WITH CONSISTANT WEIG,ON SURFACE CAN NOT CLOSE VALVES- SHUT IN WLV AND BLEED OFF UPPER LUB TO CLAMP WIRE AND PULL BLEED WELL TO 200 PSI TROUBLE SEALING WLVS WITH ELINE IN BAD CONDITION MAKE MULTIPLE CUTS AND SPLICES OOH WITH TOOL STRING AND ABOUT 20' OF ELINE LAY DOWN LUB AND CHECK FOR WIRE THEN PICK BACK UP RIH/W 4.75" LIB TO 48' SLM SET DOWN W/T LIGHT FALL THRU CONTINUE TO 283' RKB W/T FALL TO 1270' RKB POOH,RIH/W 4 1/2" GR /W BAITSUB/W 4.55" 3PRONG WIRE GRAB TO 1560' APPEAR TO BE IN FLUID TO 5380' SLM (5398' RKB) W/T WITH HEAVY OVERPULL COME FREE POOH TO SURFACE OOH/W NO WIRE LDFN SECURE AREA AND WELL ARRIVE AT PWL SHOP AT 24:00 NOTE; RECOVER 77 ' ELINE AND ELINE TOOL STRING FROM 5596' RKB APPEAR TO STILL HAVE SOME WIRE IN HOLE. n (LAT/LONG): evation (RKB): 50-133-20689-00-00API #: Well Name: Field: County/State: KEU KU 42-12 Kenai Gas Field Hilcorp Energy Company Composite Report Kenai, Alaska Contractor AFE #: AFE $: 2011785C $1,151,984 Job Name:2011785C KU 42-12 Completion Spud Date: gp y pp p We estimated about 150' of 5/16" e-line and 16.5' of tools. Got tool drawing to Pollard slickline and they will be here at 7 am.,Rig down lubricator and crane. Secure well and turn well over to field. fish still in wellbore (2 ft gun and tools .) gpgg pg Confirm water was displaced to bottom of perf interval at 5863' md.,RIH and set 5-1/2" Geo CIBP at 5820' midppg g p p element.,RIH with 3-3/8" razor perf gun 4' in length. 6 spf, 60 deg phasing. Correlate on depth. Bleed surface pressure down to 251 psi. Perforate 5760 - 5764' NOTE; RECOVER 77 ' ELINE AND ELINE TOOL STRING FROM 5596' RKB APPEAR TO STILL HAVE SOME WIRE IN HOLE. fish in hole CTU OOH WITH TOOL STRING AND ABOUT 20' OF ELINE LAY DOWN LUB AND CHECK FOR WIRE THEN CBL .... TOC at 1850ft (excellent bond below 2250 to TD) gls 10/20/20 from 5600' to 5602' w Completion reports (sundry 320-242 / 320-280) W/T WITH HEAVY OVERPULL COME FREE POOH TO SURFACE OO p( . Get ok to perforate from 5853' topgp 5863' with 1005' psi on tubing. Spot and fire gu ,RIH w/Halliburton CBL tool at 50 fpm and tag at 6436'. Logged up from 6436' to 1500' at 50 fpm.g Found TOC at 1874'. Se pp p g Recover a total of 164 bbls of wellbore fluid. 6/21/2020 ARRIVE JSA PERMIT R/U PT TO 250 PSI LOW AND 3500 PSI HIGHTP - 180 PSI RIH W/ 4.5" WIRE FINDER W/ CENTER SPEAR BAITED TO 5166 W/T TO5174 POOH NOTHING RIH W/ SAME TO 5202 KB S/D W/T TO 5220 KB GET OVER PULL - POOH - NOTHING CHANGE OUT DEPTH COUNTER,RIH W/ 3"X 5' DD BAILER TO 5523 KB S/D W/T TO 5541 KB POOH - FULL SAND RIH W/ SAME TO 5508 KB S/D W/T TO 5527 KB GET OVER PULL - POOH - FULL SAND RIH W/SAME TO 5508 KB S/D W/T TO 5535 KB POOH FULLSAND DID HAVE 1 OVER PULL 2000 RIH W/ SAME TO 5514KB S/D W/T TO 5529KB POOH- FULL SAND,RIH W/SAME TO 5513 KB S/D W/T TO 5534 KB POOH FULLSAND RIH W/ 4'' BLIND BOX TAG FLUID AT 1133KB RAN UP AND DOWN TO VERAFY,RIG DOWN LUBRICATOR AND EQUIPMENT. SECURE AND TURN WELL BACK OVER TO FIELD. GET UNIT READY TO GO TO KDU -9 IN MORNING. 7/17/2020 Sign in. Mobe to location. Spot equipment and rig up to lubricator. PT to 250 psi and 3500 psi high.,RIH w/GPT tool and tie into OHL. Tagged at 5531'. Not Deep enough. Try pressuring up a few times. Didn't work. POOH,Wait on orders from town. Rig down. 7/21/2020 ARRIVE KGF - JSA - PERMIT - TRVEL TO LOCTION - CHECK EQUIT - CHANGE TOOL STRING R/U S/L PT TO 4000 PSI - GOOD,RIH W/ 3'' DD BAILER TO 5517 KB S/D W/T STILL VERY STICKY - POOH - FULL THICK MUD RIH W/SAME TO 5519' S/D W/T STILLHARD STICKY - POOH - FULL THICK MUD W/ SOLID PLUG BLOW WELL DOWN TO 2500 PSI RIH W/SAME TO 5519' S/D W/T STUCK TOOK 3 OJ LICKS AT 1650 TO 1700 LB TO GET FREE POOH - HARD PLUG THICK MUD,RIH W/ 2.25 DD BAILER TO 5519 KB S/D W/T GET STUCK 4 OJ TO GET FREE W/T POOH RIH W/18'' DIGGING TOOL TO 5520 KB S/D W/T STILL STICKY W/T - POOH RIH W/ 3'' PUMP BAILER 8' TO 5519'KB S/D W/T -POOH - FULL THICK MUD RIH W/ SAME TO 5520'KB S/D W/T - POOH SAME WELL AT 1500 PSI,RIH W/ 2.25 DD BAILER TO 5520KB S/D W/T GET STUCK 5 OJ LICKS TO GET FFREE BLOW WELL DOWN TO ZERO RIH W/ 4.60 CENT TO BETWEEN 150 FPM TO 200 FPM AND TAG AT 5520' KB. FL - 799'. THE HALLIBURTON PLUG IS 4.24' OD. SHOULD GO IN HOLE FINE.,RIG DOWN LUBRICATOR AND EQUIPMENT. SECURE WELL. HALLIBURTON WILL BE BACK IN AM TO SET PLUG AND DUMP 25' OF CEMENT. 7/22/2020 Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2500 psi high. TP - 0,RIH w/4.24" OD CIBP and tie into OHL. Ran down to 5515' and got sticky. Decided to set plug at 5513'. Ran correlation log and send to town. Got ok to set plug at 5513'. Spotted and set plug w/0 psi on tubing. Lost 400 lbs of line tension when plug set. Pick up 30' and go back down and tag plug. POOH. Look like a good set.,RIH w/2-1/2"x40' dump bailer filled with 17 ppg cement and tag plug at 5513'. Dump 6.69' of 17 ppg of cement on top of plug. POOH. Good dump. Made 3 more bailer runs of 17 ppg of cement and dumped on top of each other (26.76' total cement). CIP at 1730 hrs. Est TOC - 5486.24'.,Rig down lubricator and equipment, Secure the well. WOC 7/26/2020 PJSM w/ Crew,RDMO T/ Pad 14-6 well KU 42-12,MIRU t/ 42-12 Spot all units,R/U and test BOP 250/4000 All components SLB,Secure euipment and r/d down test Equipment. 7/27/2020 PJSM,R/U Inj head and test t/ 250 /4000 PSI 5 mins each low/high,RIH w/2.30 nozzle and tag toc @ 5481,P/U and Blow down well dry pooh t/4000' RIH and Cont Blow down well POOH leave 1000 PSI on Well Head Tot Recover 112 bbls All good,RDMO Mobilize F/14-6 t/ France # 1 7/29/2020 Sign in. Mobe to location. Spot equipment and rig up lubricator. Have pad op operate the tri-plex. PT lubricator to 250 psi low and 3000 psi high. Arm perf gun,RIH w/3-3/8"x13' (loaded with 3-1/8" charges) 6 spf, 60 deg phase tie into OHL and had to season the brand new line. Ran correlation log and send to town. Get ok to perforate from 4203' to 4216' with 856 psi. Within 1 min pressure went to 1110 psi, 5 min - 1159 psi, 10 min - 1161 psi and 15 min - 1163 psi. POOH. After HLB got in lubricator, bled press off could not get the hoist to move. Trouble shot and pad op found,a wire pull loose. Fixed the problem and lowered tools out of lubricator. All shots fired and gun was dry.,Rig down lubricator and turn well over to the field. 8/6/2020 MIRU. Verify gun dimensions. 3-3/8" x 13',PT lubricator to 250/3200 psi. MU guns and measure distance from CCL to top shot (14.5'). Surface weight of BHA = 625#.,RIH with Perforating BHA. Correlate with reference log and confirm depth with office. WHP = 1050 psi, flowing ~ 1.8 MMscfd.,Pinch well back to ~ 800Mscfd and WHP = 1100 psi. Perforate 4203' - 4216' with 3-3/8" guns w/ 3-1/8" charges, 6spf, 60 deg phasing. POOH. Shots fired with small amount of liquid which appears to be oil/hydrocarbon in bull nose of guns.,RDMO CIBP @ 5513 ft pg Got ok to set plug at 5513'. re-perf zone 4203-4216 ft RIH W / 3'' PUMP BAILER 8' TO 5519'KB S/D W/T -POOH - FULL THICK MUD Perforate 4203' - 4216' w g( g) Get ok to perforate from 4203' to 4216' with 856 psi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enjamin Hand Digitally signed by Benjamin Hand Date: 2020.06.04 08:35:22 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.06.04 09:50:57 -08'00' TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 4 1 36 Yes X No Yes X No 40 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 20.43 Type I II 230 2.4 Class G 135 1.16 5 24.25 21.73 Hanger 13 3/8 TSH Wedge 1.30 21.73 1,462.72 1,486.97 24.25 Pup 7 5/8 29.7 L-80 TSH Wedge Tenaris 2.52 Casing 7 5/8 29.7 L-80 TSH Wedge Tenaris 1,524.38 Casing XO jt.7 5/8 29.7 L-80 TSH Wedge Tenaris 37.41 1,524.38 1,486.97 1,692.70 1,691.38 Casing 7 5/8 29.7 L-80 DWC Tenaris 167.00 1,691.38 Float collar 8 5/8 BTC Casing 7 5/8 29.7 L-80 BTC Tenaris www.wellez.net WellEz Information Management LLC ver_04818br 3 162.00 Ftg. Cut Jt.Ftg. Balance 83.49 1,776.19 1,692.70 1.32 47 No. Jts. Run 43 4 Length Measurements W/O Threads Ftg. Delivered 1,912.62 Ftg. Run 1,750.62 Ftg. Returned 12 107.8 18.00 20.43 RKB to CHF Type of Shoe:Innovex Casing Crew: 21 hydro form 1,778.001,787.00 CEMENTING REPORT Csg Wt. On Slips:37,500 Spud Mud Weatherford No. Jts. Delivered 15.8 39.7 Bump press Return to Surface Bump Plug? 1:45 5/26/2020 0 4.5 15.8 5 100 535FIRST STAGE10.5Tune spacer 40 BTC 2.02 1,778.21 1,776.19 Csg Wt. On Hook:50,000 Type Float Collar:Innovex No. Hrs to Run: Setting Depths Component Size Wt.Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.KEU KU 42-12 Date Run 25-May-20 CASING RECORD County Kenai State Alaska Supv.S Hauck/ J Richardson 147.5 41.5 106 Spud mud 76.5/77.6 1267 83.5 HES cmt truck Ft. Min.PPG8.9 Shoe @ 1778 FC @ Top of Liner1,691.38 Floats Held Casing (Or Liner) Detail Shoe 8 5/8 79.3 2563.5 Rotate Csg Recip Csg gls41 bbl cmt TD Shoe Depth: PBTD: Jts. 1 2 8 1 6 1 9 1 93 X Yes No X Yes No 20 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: ZXP Liner Hanger Casing (Or Liner) Detail Shoe RA Marker JT 5.5'' CDC HTQ JT 6 PPG9.1 Shoe @ 6521 FC @ Top of Liner 1636 72 106 20 86 2500 6% KCL PHPA Mud CASING RECORD County Kenai State Alaska Supv.R Pederson / J Riley Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.KEU KU 42-12 Date Run 4-Jun-20 Setting Depths Component Size Wt.Grade THD Make Length Bottom Top CDC HTQ Innovex 1.78 6,521.00 6,519.22 1,669.62 1,636.18 39.03 5,437.53 5,398.50 5,398.505 1/2 17.0 L-80 CDC HTQ 3,728.88 6 5/8 CDC HTQ 5 1/2 17.0 L-80 CDC HTQ Innovex No. Hrs to Run:12 33.44 1,669.62 FIRST STAGE10.5Tuned Spacer 40 9.1 2 50 1540 6,477.00 15.3 23 Bump pressBump Plug? 126/127.6 2500 20 Halliburton 6,521.006,521.00 6,436.00 CEMENTING REPORT Csg Wt. On Slips: 6% KCL Polymer mud Csg Wt. On Hook:Type Float Collar: Type of Shoe:Innovex Casing Crew:Weatherford 12 83 Floats Held Rotate Csg Recip Csg Ft. Min. Baker Flex Lock ZXP www.wellez.net WellEz Information Management LLC ver_04818br 2 23:00 6/4/2020 1,639 One per joint, every joint 5.5'' CDC HTQ JT 5 1/2 17.0 L-80 CDC HTQ 39.99 6,519.22 6,479.23 Float Collar 6 CDC HTQ 1.25 6,479.23 6,477.98 5.5'' CDC HTQ JT 5 1/2 17.0 L-80 CDC HTQ 40.88 6,477.98 6,437.10 Landing Collar 6 CDC HTQ 1.02 6,437.10 6,436.08 5.5'' CDC HTQ JT 5 1/2 17.0 L-80 CDC HTQ 320.99 6,436.08 6,115.09 R A Marker JT 5 1/2 17.0 L-80 CDC HTQ 40.29 6,115.09 6,074.80 5.5'' CD HTQ 5 1/2 17.0 L-80 CDC HTQ 240.39 6,074.80 5,834.41 RA Marker JT 5 1/2 17.0 L-80 CDC HTQ 40.33 5,834.41 5,794.08 5.5'' CDC HTQ JT 5 1/2 17.0 L-80 CDC HTQ 356.55 5,794.08 5,437.53 Type I II 200 2.23 Premium 105 1.24 2 TOC at 1850 per CBL) CBL indicates excellent cement from 2250 - TD. gls 10/20/20 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/16/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 42-12 (220-045) MUDLOG DATA Please include current contact information if different from above. Received by the AOGCC 07/20/2020 PTD: 2200450 E-Set: 33564 Abby Bell 07/20/2020 as"Whe R:nu -JS has, SSlmpN; aWaeoawuu xxxxxxppckmAivA3moL3Y.28M a140ne1b: I�PL.mI Hi Mike, We will review the Sundry Report for KU 21-07X and get back to you as soon as we can. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commissoon (AOGCC) CONMENIMNryNOTNE:r ailrzuge.ea+w maruenmentx— mWri moron mann. wmm<om v woor, sore d nWu,ence fixe--e—olio... -'wmunw nuvr,—imxvwm w.bame of Wos,,wx nev or oxim, lYwelf yu—x m sn .t .—as, recopal lr Jr wa Ngoc. wet or maU4 lnuMl nreYoum ma[m]� rx meMetl rn'.pkmolq wn deau0ek:e NrMu[nmuNryw,aro mrl.n awae su.ao. �� nsan e From: Mike Quick <mquick@hikorp.com> Sent: Monday, July 13, 202012:41 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Ce: Riese, Melvin G (CED) <melvin.mae@alafka.gove; Boyeq David L (CFD) <david.boyela@alaska.gov>; Roby, David S (CED) <dave.roby@alask SgoY>; Donna Ambuz <dambzoz@hllcorp.com> SNbje4C RE: (EXTERNAL) KU 4212 (PTD 220045; Sundry 320280) -Request Hell, Steye— Hilcorp has submitted both the 10-404 report for the plug and cement work on KU 21 WX, and a letter requesting the removal of the spacing exception requirement for KU 42-12, as outlined below, in the email chain. Hilcorp will wait to hear back from the AOGCC on the request for the KU 42-12 before we saturate that well. Please let me know if you need any additional information on the submittals. Hope that you had a great weekend. Thanks, Mike From: Davies, Stephen F (CED) (madtmSteve rt vb toeuiska Soil Sent: Wednesday, July 8, 202010:32 AM TO: Mike Quick <mouickrdhdrom coma Ce: has, Melvin G (CED) cmSmm r isata a,k, um,x; Royer, David L (CFD) <davidlnve,20, asb an,; Roby, David S (CED) <deve mitebalaha Sov ; Truck Hallett <tKIIIIHOWIrnm cnm> Donna Ambruz <dambrmnbimm to, Subject: RE: (EXTERNAL) KU 42-12 (PTD 220045; Sundry 320280) -Deepest Hi Mike, Hope all Is Well there Q: My question is, haw dr, we proceed with KU 42-12 perforations after the work is done on KU 21-07X1 Once the plug is set in KU 2102X, the need for the spacing exreytion for KU 42-12 goes away, correct? A: Correct. Q: Does Hilcorp need W file any additional paperwork on KU 42-12 to remove the spacing exception requirement noted on the sundry? A: After Hilcorp performs the plugging operations on KU 21-02X, please submit a Sundry Report (Force 10404) documenting completion of the plugging operations and successful pressure testing of the plug, and than simultaneously submit a letter requesting AOGCC remove the spacing exception condition for the proposed shallow perp from the Sundry for KU 4212. Please of me know if Iran help you further. Best Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONF/QFNTIa11LY NpaNE: n.0 email meruaa MUJW aMarta[I.me.M.wnulwlntwmar�Irwn LL.ealaJa OJard4e(nnarvaLL-n [omn45[n (g00rq,irue W llukaaMUltt Yemk ueolMeNmMelrppkngrln mW x'mminaMNenld angrorglvkae4lMorvmueniM1eunautlwnzMmYw, uugdtlmurc Nnxaldormarknmryywlau ruaeerlMenllaw,npu—munlmeMtlrMdamdrFuemlFdemeMemlt NtlwxnrnssnMarlorwaNry2 artl,fotlotne40eCcemme NiMMstaLelnuMryumyeu, morn 3:we Mxnar9axA31334warv.n m...s®.e.u..... From: Mike Quick <mc—lotiblimp cur Seat: Wednesday, July R, 20202:54 AM TO: Davies, Stephen F (CED) <yleyp,dayf Cc: Ruse, Melvin G(CED)<MgtNMrixsara.aUakao,w>; Boyer, David L (CED) <JJSadjaudL2ladakaSnm;Roby, David s(CED)<davembv®alaskaSov>;Trudi Halleft<tlullan9hdrmornm>; Donna Aanbrux <dembrua0h,lom,oma Subject: RF. [EXTERNAL] KU 42-12 (PTD 220045; Sundry 320280)- Request Hello Steve and the AOGCC team- Hilcorp received the approved sundry for KU 4212 yesterday, thank you for getting it back. The approved sundry states that a spacing exception is required for this well. We also received the approved sundry for the KU 21-07)( well (PTD 206-029), sundry 320282, that Isolates the only perforations in the Sterling undefined pool as discussed below. Hilcorp will be setting this plug per the sundry in the next couple of days. My question is, how do We proceed with KU 4212 perforations after the work is done on KU 21 07X? Once the plug is set in KU 2102X, the need for the spacing exception for KU 42-12 goes away, correct? Does Hilcorp need to file any additional pa pefwork on KU 4212 to remove the spacing exception requirement noted on the sundry? Picture advise on Path forward on KU 4212 work per the sundry 120380. Thanks for your assistance, Mike From: Davies, Stephen F ICED) Ima;lte.love Itic—c labsla cove Send: Thursday, July 2, 20209:13 AM To: Mike Quick saryounconchilcom cores On. Rinse, Melvin G(CED)<melv,o ninsylbolanilk,a it Bower, David L(CED)<Ezvidbnwer0g task, noi Roby, David S IUD) U=vc rolwktakip >; Ted Kramer<fkromeragnicorn mm>; Trudi Hallett <OhallettklMimr Subject: RE: [EXTERNAL] KU 42-12 (PTD 220045; Sundry 320-280) -Request Al Mike, Hope all is well withyou and your family. I conferred with Dave and Mel about your proposal to set an isolation plug in the tubing of KU 21-02X. This Is acceptable, but AOGCC requests that after the plug Is set, please dump bail minimum of 25' of cement and then pressure test. As always, please submit a Sundry Application to obtain AOI advance approval for this proposed operation. The Staining Undefined Gas Pool perforation in KU 2107%must be isolated as described above prior to perforating that Pool in KU 42-12. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) fpNFIOFNIL111rYHORQ:Tut —.1 messaae, lI vIvic aryarta ra NMmvtiin kwn u4 AvYaoYaM Wr cow"RocnCmmmlWm (MGCCh tratedAli antler lw 1. sde ueolne MCMee redpen4qn mlosonsln awspern kaw, mniftlInk—wenn TM unWiplrM renew. ure w ai1al-1 Mgouns, vMmad¢er leEnal y- I—v— -r,.,w-tt tion. tori pnsehe4 M1..fat awlry w kwners c wiry tE.e>WC<Isaware or nn rci. I. It top,, mma¢Sce nMesn W}-]93-V}durr...n ®. From: Mike Quick <mauicbg Ik ms Send: Wednesday, July 3, 20202:32 PM TO: Dai Stephen F IUD)<Aeve thyeslntalaska Dow>; Truth Hallett<tha Rectutiffinflicon, turn Q: Roue, Melvin G(CED)<madvi rinsectea asks s; Rover, David L(CED)<daon Mver2Oaaak> yet >; Roby, David S RZED) <daw rnhyfirs b ini Ted Kramer <tkra emphHrn Subject RE: ]EXTERNAL] KU 42-12 (PTD 220-045; Sundry 32028(1) - Request Steve - We would like to discuss the option of isolating the open perforations in the KU 21-07X well as an alternative to applying for the spacing exception. KU 21 07X has not produced since 2013, when the well died due to water break though. Hilcom proposes to place an isolation plug in the 2 7/8" tubing of KU 21-07X above the perforations (this is a gravel pack completion), to isolate the open perforations, ensuring those perforations cannot be produced. Do you have time to discuss this alternative? I len you a store message as well. Thank you, Mike From: Quit., Stephen F ICED) Imailto:aeve Aavie,eci laskacavl Sent: Wednesday, July 1, 202010:04 AM TO: Truth Hallett <rhaArrr®hilrmo toms; Mike Quick <mmdrtk)hurom rn Get those, Melvin G(CED)<melvimdae(gabha ones;Boyer, David L(CED)<dai bovenklobska tow;Roby, David S IUD) ketwo mbio.fivsk, can Ted Kramer <furamortandrnrncrams Subjects RE: (EXTERNAL] KU 42-12 (PTD 220045; Sundry 320280) -Request Trach and Mike: Thank you for your quick reply.) appreciate your help. My quick well log correlations place the top of the Stenon 3 Gas Pool in well KU 42-12 at ki MD. This pool is governed by CO 530A. Any perforations in KU 42-12 shallower than this depth will lie within the Sterling Undefined Gas Pool, which is governed by statewide Rear,tion ?n AAC 25 0<S My reatling efthis regulation indicates that a spacing exception is needed to perforate the Sterling AT sand within KU 4212. Subsection (1)(41 of that regulation states in part: Yf qac M1az Eeen tllssvvertd.., s well may rro[Ce tlalpeO w mmplecetl rMser roan 3,000 htt ro any wNl WYltlrrg ro w [apaDle olpmtlutlrp fiwn Me samepppl.• [Empllaw are mine.l On both Hokorp's and AOGi maps, Hikorp's planned perforations will lie about 2500' from perforations between 3479'and 3487' MD in well KU 21-7X that are open to—and therefore capable of producing from—the Seeding Undefiled Gas Pool. Please submit an application fora spacing exception for the planned perforations in KU 42-12. Since a Notice of Public Hearing most be Published and a 30 -day public comment Period is required, this process should take about id to eight weeks to complete. Please let me know if you have any questions. Thanks and stay safe, Steve Dayies Alaska Oil and Gas Conservation Commission (AOGCC) IPNf/PFMIWITYNOFHF: rid mesaialrcWSnwynown—amt m'wirwabnhwn Neuers Ou aM am micremum os, mmavm Typiprix va,wo-nel: lar me nor w ti WeMM ricstRi r itaycoutty, woodman an4lm ervii R., 1. rMetroww"now"ion" systrmngnmw.—ar—kinml hw, Ilpu man vAnrendrJ waltr oNle small switur eb A MJwr fie uNry"ints"I R aM, ourne" CGCeuawert NW Masw.."tg a I.. cros Nave anlvatsai or n...., it— Fmm: Trutt Hallett <tlullen9hilmm cams Sent: Tuesday, June 30, 20204:35 PM Tee Davies, Stephen F (CED) amso my wsk)a a@a cow; Mike Quick <mmctr6flhwan, mm>; Ted Kramer <tkramorsoulrom cons CK: Rine, Melvin 6(CED)<melvin rosgigaleban.;Bull David L(CED)olzvul bowuliza6ab ov>; Donna Arnihm,<damhrm(dhiIrmo >; Matthew Petrowsky mpenawskv®hOro a; geryamn Siks<beik,0hjrn Subien: RE: [EXTERNAL] KU 42-12 (PTD 220045; Sundry 320.283) -Request Hi, St. — Here is the structure map on the Sterling Pool 3_AB hours , everything above this horizon Is the Sterling Undefined Pool and higher, Annotated (in white) the distance (which can be seen on the bottom of the image— red arrow) between the KU 2101K perfs(old Undefined Sterling Pool A6 sand perfp and the new KU 4232 well. The only intervals that have ever been perfed within the Sterling Unchumed pool are the green blocks along the KU 21-0x wellbore (which are not active). 'The pink blocks am, the well cies are only PROPOSED pens that are populated In the Petrel project. Please let me know if this satisfies your request. Thanksl -.._... n 4l :a»at R+AHIOu FC 1p z4af)pVy Oasis nllK TrlAde. Trudi Hallett lfcserroirLiiginar Arn:iiA.cn'i'I'eani llilnrp AL+Av.11 (' Hilcorp A cnmPana Built an EmM, thAlnn®hilr..m curn 0 9077778323 ( 9073016451 Frain: Davies, Stephen F(CED))m:mite ve daea.0,1-k.. vovl S,hM: Tuesday, lune 30, 20202:59 PM TO: Mike Quick<mnnirk®hitrnr m>; Ted stoamemeduccum co U: Rose, Melin G(CEO)<malv'n=c9aoebonvr,Boost, David L(CED)<daviM1hnwnMa6Qa anv>; Trudi Hallett<MallrnMHJrmm>; Donna Ambmz<dambrnr6lhitrw > SukgW: (EXTERNALI KU 42-12 (P 220-045; Sundry 320-280) -Request Mike and Ted, Since Hikorp plans to perforate the Sterling A2 sand, please provide a map of all nearby wells and KU 42-12 displaying any perforations that Ie or will lie shallower than the top of the Sterling Gas Pool to demonstrate that a spacing exception is not needed under statewide regulations. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) ... NaTIQ: Tnb sinal mevy vo,,aM ana4mmu, nwalrs ww.0—ewm Jt.".b, aMsoeammtlm C-vuo- Poss", suis ca a'..aM k. Te ale ue of Y neMM nue—In, n may cp.Y1,..11O roe soza w akaazftl , i nlNemlmkenn lnfmmv rvulu uwnwun Ae+epwmn Dw l9al�}Evorvsul'.- nou.,- erur<ar -a w, anon Tanana Nu—`t dean a 2 xnFwrluxssnry (axardry RvN m nti n vwvn Mlra 1.o From: Mike Quick <rznnitk®horn Sem: Tuesday, lune 9, 2020 12 :44 PM n� To: Davies, Stephen F(CED)<S ve davee(Nzlada so >; Ted Kramer 4kramentrulrn Ce: Schwartz, Guy L (CED) <wn,sduvamsca6rk, ov>;Boyer, David L(CED)<davidhre..le aa4a,z >; Truth Hallett jibellenismicom com>; Donna <darahr,aPhdrouncom SubjM: RE: ]EXTERNAL) KU 42-12 (PTD 220.045; Sundry 320242) Question Hello Steve - It appears that those two upper perforation intervals are above the Sterling Gas Pool 3, Please remove/strike those perforations (4203' to 4218' and 4027 to 4051'MD) from this sundry application. If we work up hot, to these zones, we will resubmit a sundry package with the necessary spacing eacep0on at that time. Thank you, Mike From: Davies, Stephen F (CED) ]mailke Steve day eSPalaSka cwt Sem: Tuesday, June 9, 202011:39 AM To: Mike Chuck <mnuickishil-r, Ted Kramer<tkamerlah'Im Cl: Schwartz, Guy L(CED).c«mar usala,k .n;Bpye,David L(CED)<dav,dh—r20,i,.ka Subject: RE: ]EXTERNAL) KU 42-12 (PTD 220-045; Sundry 320x242) - Question Mike and Ted, Thank you for the digital well log files. lappreciate yourhelp. Question: Do Hilcorp's proposed perforations in KU 42-12 from 4203' to 4218' and from 4029'to 4051' MD lie within the Sterling Gas Pool defned in CO 510A, or will they Ire above that pool? If they will be shallower than the top of that pool, they are subject to statewide spacing requirements, If so, please provide a map of all nearby wells and KU 42-12 displaying any perforations that lie shallower than the tap of the Sterling Gas Pool to demonstrate that a spacing a seeption is not needed for Hilearp's planned perforations. Thanks and stay safe, Stews Davies Alaska Oil and Gas Conservation Commission (AOGCq CONiMENIVIRYNOIIQ: TM Smit mange,-oova arNaaxama.u,—I-Inl ---s- Nsoaaz� yipncl,.reaumw.neivkr oxidewrnnelme. nw,perau). it mrywnum onfiamrm mq/erplHlegM oaam�arbn.TMa.utlwrla inin—uuara'xWuagw[I,Inl—"-.1-in,me., wars, l[w.Ilycuaemur1au. rxgbm M Na. -I omi n xMwur omwlrya I—vin, n, ant, m Wn ox PWC'elsrrxrt 1. mount In virally o ropu, vmlwsvevea"..t vaz-]9a-IR0aar.... azo From: Ber min Siks<hvik.®h,l,,m nm> Sem: Monday, June 8, 20202:05 PM To: Mike Qpick <mnnNkaahornm rr.au; Davies, Stephen F (CED) -Steve dzv e.®ab<ka m Cb TM Kramer <kkkamen0h co Wbi RE: ]EXTERNAL] KU 42-12 (PTD>220045; Sundry 320242)- Reticent Th Steve, See Me attached Log Dona for KU 42-12. Cheers, Ben Siks Him Silks Geologist- Kenai Asset Tw nl Office -907-T➢-8388 Cell ---907.229-0865 b^ke/nll.ilm From: Mike Quick Sent: Monday, June 8, 2020 TAR PM To: Benjamin Sills <baaok@Wlrn Cl: Td Knimmor <11a er9Mlrn !tabled: FW: [EXTERNAL] KU 42-12 (PTD 220-045; Sundry 320.242)- Realest Ben - Please see the request from Steve Davies below and let me know what you have to satisfy his request. Thanks, Mike From: Davies, Stephen F (CED) Imailtasterve dawef®ali eKe ww] Sank: Monday, June 8, 20201:44 PM To: Mike Quick IA drk®Elco Subje .[EXTERNAL)KU 42-12 (PID 220-045; Sundry 320242) -Request Hi Mike, Hope all Is well with you and your family. We're all fine here. I'm reviewing hiccup's Sundry Appfeabon to complete and perforate this well. Could Hikorp please provide digital well log data (GR, SP --if available--reslstivity, and porosity) in las or ASCI table format so that I can revive the proposed perforation intervals? I appreciate your help. Thanks and stay safe, Steve Davies A0 CC CONfIDFNl411/lYxm/(£: TnunmrlmnwelW Wlnamawanmenu romrminrwmario. xormecyewoliawcas cowrvrtwneommuvm lnttry.mredswYa aM'urorrle ede walMemuMea r«rpmryl.lvmaveonuinwnuamrgl mNorprclegwilMwmxlonlae um�MueKmiew. mewdymwdyu'FlMpmarmnn¢y M1dal•5ratrerlaEnal law.lryouartan unlmeMearGpemdrFXeivll,pesuaektek uiNVMfinr uNry«(awartirye,aM, wrM1arrMPWCCkawert dtlumnuYelnserdlry rmyw.avnun Nerenwmmm]�193�133kwr MHMMXm/4aenYnelbn.dmbbm,wmpYdrtltlwiel�imllheYkM pmNpXM.I eirsrvMretlW emre Fvw.gevre lm¢EaMYmebM wpYleNmmmlorbkpwrenneremmd�ybre nywMnmWm�Ww,IMnpmrgryvlW MmamXNb byebuhrrewpe. VIYk YI reawlb un MMmbMbeY[tl M4ewnuvldNlwv, tlh W nmewWbdMXGpbXbemue Xmt NeamvaM vamnYmbn,ppeMp.awd W neuq W vryawwrenYwltlMNuenehvnwlM g4inera4. W remwaiOpMF auxpMrybemrprXFwvipaN W tlxmtlp4tl YaW mrryMwnvYmvmmeraemvv nmmNeravvwevam. lM Fbm�bn eonYlme F nu vnstl nevge k m-Merdal aM rrv/ w heap/ pMlbpea mY M1 Imer-0M orry b nq w d Pa MLL14al v artiy mn.1 a Ww. Irwu w M a+IXMM retiAhw p X r[u Iwa IwNM Xv nuuye F anoe, ryu m IvaCy rcnxeWMF� ewleeem:mmn, aXmewn«mpvdna emau4xpry piX.nX.e. nyouwwr.wrvoemXomwlnaoor.pFarmpwdMhYlMMupwu.nem.tl«4kpm. Xma ummegwXm.raar4Y4aapwa,uXnpompyampamawmN Nti4 en nawww ...... mMm m vvde rIe mnmmM el ruun, n 4 M eeKa'alelury er ua rxgkX to alwe wl W omwn bemaXhn apmha, m w al w nwpe w env XueXmX w.I mr alwwry aMa tr Nwne or aw. M mpmabl Iry X a«ptM ey M mmmM In uw rryw eM tlw renpkM vbup nM «n rv>I rlrw vna dMr tlreXa o X w W Mn apopM. MhanN VMakavmlllrbweMi011Miel��mpYn deYsanoib apleq palreWlMb eyOM YYMXeaeX/brMwdWlNrvtlwlwedMnmM e[are.IlyouwrolenMYNblapYlernyeu MrlwNeltlilnuay Fmw.Ywrm Nvp/ am.n Mhrleawm. you XiwmmMOawemwFmm..pmw pmvaebnruXh wermumwrepnr Xkglownul..mr.pno..m.Ileerhw.a.eee..e.IrplolruNw p.11r.rlrpr vmtleeX mmlr.eleua Iluo-nn Xl.IruvavuuemmeYnpnorFwm, ahmenlpolewlbdnXrsphdmeuwuXarewwrvnwlXulenepwry.orwdn4lueuaewmy madammaw Imaereleehamamgwnewau. xe rn{mtlewM 4 vwepne b XIe mmalq F nY epem w eX Iea'pvn Ywb renr on vuen vpuv vX alnr elmY u a muXna a{prmele. oo^evpa'b omMarNlvMmv/ pekwN p4lkGa plXklmaMamrybM wola.MM1YISIweXM w«oevep'e. Ityww MmwMW rxlpalYwvvwllnw mvk.'eanXlmugalo.mr. puvnlmty asNel.9an, w wY d M vnep 4 tlkn/ p[Naba. II you Nw rwNM qY ernll In anw, pbw pnIxNMY riopN w ey nom rntl m YYpMr. n ne of W Ye qnw wvrNr Y YM1a etme. Men ganryy eM {pllurelXry eaMe We mwpe. wkv�WM1amebNN4rmmpmrFtlmrepe WEV Ixp!mlXwutl®rryeeuNFwvNeMar WebvvXmmlearvvpPOVule. -wm, vimM,wwal WVllwpM uryaXwlnlerp WlMalv✓W/aXM trghenaoraw.W rain: Tv, BW}C nv:larwwliv nxzz (moxxoas; a„w axi>mJ-ra�mr yMvisaw Wri'30A11:urRan AlbOmub: ems' l Victoria, I overlooked sending a cc to you of the email below as I thought Mel was overseeing Cook Inlet while G W Is out of the office. If the path forward for Hilcorp that I outlined Is not correct, please let Mike know ASAP. Dave, Dave, and Mel all concurred with my suggested path forward. Cheers, Steve 0 [pxnMNl/AOIYNOT�a: rn mevye,mwexe,manxi...mk,eom,wxnum,nonr,Dino.nkYaala�ea.m,ve,..umwmmiwmlaoac9.zukNnmt„marw ueukueor:nemkm.a r.ugenWl.n rmnanea a.am nklk4a,iimmm .rho v.wuoy�:ra,rm m>nmv N:vmlmo-m,rk„ .nko.rre.,,iimvi wv,m,.�.n.umm,�,Demo,mu.m.nee,,.xxkn.uwv:n,:,.,cryo<e.,...ann...q+omnn,mue<ir...,. Nmmxmmtt„mrynkvou. �„krrnwn ome,�spr.aasazma,,..,. a,.,..®. Frain: Drvies, Stephen F (CED) Sent: Wednesday, July 8, 202010:32 AM TO: Mike Quick <mquick@hikorp.com> Ca; Rose, Mebin G (CED) <mc1Wn.nxse@alaskagov>; Boyer, David L (CED) <davidbcwr2@alaska.gri Roby, David S ICED) <dave.roby@aWska.gov>; Truth Hallett <thallatt@hilcorp.coni Donna Ambma <dambruc@hilcom.com> Subject: RE: [EXTERNAL] KU 42-121PTD 220-045; Sundry 326280) -Request Hi Mike Hope all is wall there. Q; My question e, how do we proceed with KU 42-12 perforations after the work is done an KU 2107X? Once the plug is set in KU 21 07X, the need for the spacing exception for KU 4212 goes away, correct? A: Correct. Q: Does Hilcorp need to file any additional paperwork on KU 42-12 to remove the spacing exception requirement noted on the sundry? A. After Hilcorp Performs the plugging operations on KU 21-07X, pease submit a Sundry Report (Form 1"ce) documenting completion of the plugging operations and successful Pressure testing of the plug, and then simultaneously submit a Wrier requesting AOGCC remove the spacing exception condition for the proposed shallow perfs from the Sundry for KU 42-12. Please let me know if I can help you further. Best Regards, Steve Davies Alaska 011 and Gas Conservation Commission (AOGCC) MFIPFNNNIFY.=.'rW—I rwer,Wu&ryaM aro.,oy<aNlntlo—v.n M1an ow.w. 0111. se eomnrm-m vvakn la0GW, low M1WF„Mla1-1M wx vwivae 1,.N w ra-uk It.. ..... J erpw arab, P'whear Macer- riw we..r<aer,—ivus nWumn wr-wren-"ir kiukertrove kw.Rye arc munlmeyMrxlpkm Nan bmail, owwdnna nMno,, we wauro ,i,asan4aatlu:NaPWCCr.— N Memwa.Inn'ane nw pa,,urian sw, Dvw ar aa).req nvvwm..u.ee...., From: Mike Quick <mn,nrkMAdrom mw Sem: Wednesday, July 8, 20207:54 AM TO: Davies, Stephen F (CED) <strve davieaal II skn vov> Ca IN., Melvin G(CED)Boyeq David L(CEO)<day,dJ.Wer>,9alz,kawn,; Roby, David S (CED) <daveroberysi env.; Truth Hallett ghalletirahilromrom>; Come AnW.Ir <da kgpL@j ikrrtn rnm> subject RE: [EXTERNAL] KU 42-12 (PID 220-045; Suntlry 320280) -Request Hello Steve and the AOGCCteam — Hilcorp received the approved sundry for 11142-12 yesterday, thank you for getting it back. The approved sundry states that a spacing exception is required for this well. We also reconnect the approved sundry for the KU 21-07X wiel(PTD 206-029), suntlry 320-282, that isolates the only Perforations in the Sterling undefined Pool as discussed below. Hilcorpwill be setting this plug per the sundry in the next couple of days. My question is, how do we proceed with KV 42-12 perforations after the work is done on KU 2107X2 Once the plug is set in KU 21-07X, the need for the spacing exception for KU 42-12 goes away, correct? Dyes Hilcorp need to file any additional paperwork on KU 42-1210 remove the spacing exception requirement noted on the sundry? Please advise on Path forward on KU 4212 work Per the sundry 320280. Thanks for your assistance, Mike Fram: Davies, Stephen F ICED)1-11,:surly, davu,10aUha owl Sed: Thursday, July 2, 20209:13 AM Ta: Mike Quick <mmicluabkom to, CC: Ruse, Melvin G (CED) <meivin nxserni nv>;Boyeq David L ICED)<&v,d bovaonalz<ka >: Roby, David S PCED) <dave rohvalalaAa Pay,Ted Kramer okiamervishilcurp com, Truth Hallett ohallettrahllrorn rnm> Subject RE: IEXTERNAL) KU 42-12 (PTD 220-045; Sundry, 320.280) -Request Hi Mike Hope all is well with you and your family. I conferred with Dave and Mel about your proposal to set an isolation plug in the tubingof KU 21-07X. This is acceptable, but AOGCC requests that after the plug is set, please dump bail minimum of 25' of cement and then pressure test As always, please suMnita Sundry Application W obtain AOGCCs advance approval for this Proposed operation The Sterling Undefined Gas Pool perforations in KU 21-07X most be isolated as described above prior to perforating that pool in KU 4212. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) [pNi/OEMMIIIYNpfKE: tkss..al ramie'. rclWre,m,n,<knenu<onralmlmwmerenlmmxenl,walartl Gss Cmverv,umcemmisrlmlanaW.Su¢ofnl,vYaatllatwrFerdeueotpemeneeanapenyFnmry<main<onaremin wymwmaes,almmmmm. rFeyreummmar.m... memammyremwd.imo�nmw. mayvwlmeammmlNerrl w..nswar...,.rlm.nd.a ralwemmmu.m.a, w.m. xyl, n, mnAmun<am�rem ww,mlre4.na, wmmtlrcmpc<�savum ma.moos,m„nelrenmvrv.mm.<rmoaommarm2aaa-tn.m.,-.w-�®, From: Mike quick <mn lrk®l'r Sent: Wednesday, July 1, 20101:32 PMS To: Davies, Stephen F (CED) <steve day estaalaske ony>; Trudl Hallett <ehallon9harm Cc: Roue, Melvin G (CED) <m -1o n mxegqu1K,ka cov>; Boyer, David L (CED) <dayd Isw r2ewlask, onvr, Roby, David 5 (CED) <daw rnM®alaska env>; Ted Kramer «kmmenflhllcnrn mm> SubjM: RE: (EXTERNAL] KU 42-12 (PTD 220045; Sundry 320-280) Request Steve - We would like to chains the option of isolating the open perforations in the KU 2107X well as an aft .... twe to applying for the spacing exception. KU 21-07X has not produced since 2013, when the well died due to water break though. Hilmrp proposes to place an isolation plug in the 2-7/8" tubing of KU 21-07X above the perforations (this is a gravel pack completion), to isolate the open perforations, ensunng those perforations cannot be produced. W you have time to discuss this alternative? leftyoua voice message as well. Thank you, Mike From: Davies, Stephen F (CED) Imo mzteve d,v a *ta Iaxka sol Sem: Wednesday, July 1, 202010:04 AM To: Tmdi Hallett<tlellett®Frken >; Mike QuKk Inmurckgmikom corns Cc: Glass, Melvin G(CED)<m .sek6yeq laska onn>; BoDavid L(CEO)<,"id lvover2e Eska coo; Roby, Dayid S(CED)<daw mMlotaUsk,ynm; Ted Kramer <tkramorhahllcommm> Subje4F RE: [EXTERNAL) KU 42-12 (PTD 220045; Sundry 320-280)- Request Tmdi and Mike: Thank you for your quick reply. l appreciate your help. My quick well 2-g correlations place the top of the Sterling 3 Gas Pool in well KU 42-12 at 4,224' MD, This Pool is governed by CO 510A. Any perforations In KU 42-12 shallower than this depth will lie within the Sterling Undefined Gas Pool, which is governed by statewide Emulation 20AAC 7� 055, My reading of this regulation indicates that a spacing exception is needed to perforate the Sterling A7 sand within KU 4242. Substation (a)(4) of that regulation states in pan: 'If pes M1as Men E6mvereE... a well mayno[%NNpNarrnmpk[e0 tlosn-Man 3,007 he3 fn eM la'tY On'lling N or upOk o/OroOutlrg horn Nesame ppp(.' [Emphases ere mine.] On both Hlkorp's and AOGCC's maps, Hilmrp's planned perforations will lie about 2500' horn perforations between 3479' and 3487' MD in well KU 21-7X that are open to -and therefore capable of producingfrom-the Sterling Undefined Gas Pool. Please submit an application for a smtingeueption for the planned perforations in KU 4212. Since a Notice of Public Hearing must be published and 30 -day public comment period is required, this process should take along six to eight weeks to complete. Ensure let me know ifyou have any questions. Thanks and stay safe, Steve Davies Alasb Oil and Gas Conservation Commission (AOGCC) CONimENTNIrTy elouni 11sx—li rteeq,, IMualre aMaara<1.m,ulw 1Mam"Fcm N,NwYanaaM6ummervaumwmmawmlaoocq. stay MA rs a. 1, In Mwk-.10- . ...."m nmwamyn<mrmw. .I",Plrkketl YJamat.Ineunwtlw,ma.-weor ElwlmueNrvAln(mmexor. v'Wy atm. weMenl I",'vs_rc umntt,Wa'v. eareol.—a, wesse sm. wnbn a. -re or bvM're,t.aM,wawa h4WK a evert .... . m..i, it m am. -- neve nzln at qo2 14224 ar ytpay iwa,,yyaxm. From: Trudy Hallett <ena en9Fdmmcnm> Sent: Tuesday, June 30, 20204:35 PM To: Davies, Stephen F(CED)< ed,v,staalasb. >; Mike Quick < :rk®l'c >; Ted Kramer <tkra erlmhlco Ce: Riese, Melvin G(CED)<melv'n fixseriii.mv,Boyer, David I(CED)<davd bcwr?rz,laskzam; Donna Ambruz<damhnvknhico >;Miethew Petrowsky wsblam itr M1u>; Benjamin Siks<hsiksuil n Subject RE: [EXTERNAL) KU 42-12 (PTD 220-045; Sundry 320480) -Request Hi, Steve - Here is the structure map on the Sterling Pool 3_M horizon, everything above this horizon is the Sterling Undefined Pool and higher. Mnotated (in white) the distance (which can be seen on the bottom of the image -red arrow) between the KU_2107X perfs (old Undefined Sterling Pool AS sand Perfs) and the new KU 42-12 well. The only Intervals that have ever been perfed within the Sterling Undefined Pool are the green blocks along the KU 21 07X wellbore (which are not active). -The pink blocks along the welllores are only PROPOSED per'sthat are Populated in the Petrel project. Please let on, know if this Sabi your request. Thanbl m.11M q one, +M, l;' sae...v i:ua TrIAd. Tamdi Hallett I ka'enn lta, n, k�.. A— Iajv If II, Al ILC Hilcorp A comp.ro BuN on E..,, (I W17, 777832 3 ( 907J016657 m m From: Davies, Stephen F ICED) Imadm=aeve day i .Paha, enol Sent: Tuesday, lune 30, 20202:59 PM To: Mike Quick <muui,,kEW ....pa ; Ted Kramer <rtamer®harnm rune Q; Elea, Melvin G ICED)<melvin rka®aLaha unv>; Boyer, David L(CED)<david bowr?A,A uov>; Trudi Hallett <th Ilenalmicorn rnm>; Dorm Ari<6—brmnobdrnre rnm> Sub)M:[EKFERNAt]KU42-12(PTD22D 575undry3202&1)-Request Mikeand Ted, Sino. Hilcorp plans to perorate the Sterling Ara sand, please provide a map of all nearby wells and KU 42-12 displaying any perforations that lie or will Ile shallower than the top of the Sterling Gas Pool 3 to demonstrate that a spacing exception is not needed understatewide regulations. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) eON{IpEMN1RY NOI/FF: iI, mal meuryeevirs.,—mxw,v'welmidmmaPon hwn tw Mata Wen[ 4u [emerveuonCmmmuslmlPoattlsoleal>I...... ,tMnk mdrMNteMetl retlgmpsl-nw [mon wnyoww vµ/arpMYeaeOiMmmhn.M uwu .ev w...—N rv`"" "I"— -w Nyweremwn[miNrrtyem MMu emrl 4kme.Yk4 r..am wiry v/wNIM R aW, foam WapgrGdawm d TeMWYelr—'a.v vis, taaxeinw.n Iva ey',aa-'.a a, wµ Foom: Mike Quick <mrndN®Mkmo mm> Sent: Tuesday, lune 9, 202012,44 PM To: Davies, Stephen F(CED)<s vedavnv(aa Urkau >; Ted Kramer<tbzmrvlabilm Ce:Sohwarh,Guy L(CED)<mwvbwaneraalastaunv>; BWep David L(CEO)<d,v,d en2®alanb o,;Trudi Hallett<rhellenpMlrommm>; Donna Amb...<damhru,0hdkco Sub]M: RE: [EKTERNAL] KU 42-12 (Pip 220045; Sundry 320.242)- Question It appears that those two upper perforation intervals are above the Sterling Gas Pool 3. Please remove/strike those per(orations (4203' 1.4218' and 4029' 104051'MD) from this sundry apPlkatum, If we work up hole to those mums, we will re -submit a sundry package with the rem... spacing exception at that time Thank you, Mike From: Davies, Stephen f (CED) [m= ie ee daysyma ask= envl Sed: Tuesday, lune 9, 202011:39 AM e To: Mike Quick <m 4d9httrr.mrnm>; Ted Kmmer<Ikra mer®blm Cc Schwarb. Guy L (CED) <e w shwarh iota asks o -m; Boyer, David L (CED) <M1=v d bray r2k3a asks en Subject RE: [EXTERNAL] KU 42-12 (PTD 220045; Sundry 320.242)- Question Mikeand Ted, Thankyou for the dieibl well log files. I appreciate your help. Question: W HIIWM's proposed pedomtions in KU 42-12 from 4203'to 4218' and from 4029'to 4051' MD Ile within the Sterling Gas Pool defined in CO 510A, or will they He above that pool? If they will be shallower than the top of that pool, they are subject to statewide spacing requirements. If so, please provide amp of all nearby wells and KU 42-12 displaying am pedombons that He shallower than the top of the Sterbng Gas Pool to demonstrate that a spacing Reception is not needed for Hilcorp s planned Perforations. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCQ CpNNpFxFyALyryxpTlQnal —.mmm,,IMunu an, —,I."marahldwmnbn ryan NeYa.ON as Ga dmemnm CmnMssim la Mort.sum.alabaMls la an ode ma.h. Me. me -It'll 11 emftlman imear'lkaM lnlamgbn. That wutln,uM —r wm ElvlmuedutAlMamnlnnmWvdatt NuarMmtl mar naouarc anmmarm4 rtlpemcfelInial , percdekC It wrbur nm unryarawar im lend. mea am AAo6CCe aaarc M me mamm In eeMlg ameta — nne pain s to"I"a3}a "'I'm A� Fmm: Benjamin talks CJ jbalpbnrnr m: SeMonday, lune 8, 20202:05 PM rn� To: Mike Quick<md«kyandk m; Dawes, Stephen F H1D) vineved=vosefalaskae U: Ted Kramer <tkramertahilco Subject RE: ]EXTERNAL] KU 42-12 (PTD 220045; SuMry 320.242) Request Hi Steve, Sam the thrashed Log DW for KU 42-12. Cheers, Ben Saks Ben Saks Geologist -Kens Asset Term 4)ffce-907-771-8388 Cell --907-229-0865 From: Mike Quid SMF. Monday. June 8, 20201:48 PM To: Benjamm Silt <Micifil cc Cc: Ted Kramer <tkiramer0h I Sublect: FW: [EXTERNAL] KU 42-12 (PTO 220(,45; Sundry 320.242) - Request Ben - Please see the request from Steve Davies below and let me know what you have to satisfy his request. Thanks, Mike From: Davies, Stephen F (CED) [mailto stave day ea®abaka aovl gem: Monday, June 8, 20201:44 PM To: Mike Quick<ramnirimshlm Subject: [EXTERNAL] KU 42-32 (PTD 220045; Sundry 320 -242) -Request Hi Mike, Hope all Is wall withyou and your family We're all fine here. I'm reviewing Hilco p s Sundry Application to complete and perforate this wall. Could bloom, please provide digital well logdata (GR, SP --If available -resistivity, and porosity) in.Ias or ASCII table format so that Icon review the proposed perforation Intervals? I appreciate your Help. Thanks and stay safe, Steve Davies AOGCC CONFIMMIW/IYxp]xY: THaemaumemye. irrcinnearnaeafmmu. a'wNmedormxionsrcm Ne Nart+alaNea Cmu.Varan WmmmbnlapKq.srmdaea4Ianranew4medrMemeeehtlnupmuq. nmunam.emnemud all .,.am maraw, Mnih uvueanamemam. t 1111.111edaueM1lnlamation maVVldrnmxorkeertllaw.IlyeuveanummmMerecipentalpesmaet peave4leul[nrMn Mnudryvinnar6gitar4w4a[LLtAOGCCRawerc d Memisutrinmeerynaoyou.roman StmpMnea9U]�]93�1}E4ar eweeegmemawmiee.einnwe.ee1won�amyr land.uaNwwne�anXs�w iereraawwtrew �ama�naeea�.ode.�a mneeauyreeuNugnenneormswekenorynueep�emwerspon11wnm�alme ,merawmeaV-eNwmremreyp eaaaaamusai teaviaInunx.b.al+core. [awrepolweniydune:peenenan.tlslueomnmumeenunim. 11 awotawnery.e-vomaa—vareall—a.aedYwdnl+mmw mwnaeewMn vmpary Mmemry lwntllerpaN W Ne napwatleudrrymernvememoteerdnwaimm6neppcplele. mnm..mam...w YeMraaYiw..Y aYwly P�vMe.ew YaxYww.mw.m. u..ax. uevYeiv.Y.r ..m.emwe. nvw.m�wu,m.m.tl,.eo.e.,.Y=� rra awv.emYm....wm.rar.rw.Y mr.w 'xmraaw.rvtl��M„u.,.e.u�ewon.mPramY.m.a Y.YYh w>.ax.e. xY.�r �.w rera.euY.m.Y m«,.r.PY.. imw.w�wnvrwmw..m.uerwvm.�.uuw..bn. P� •+„e., �. wae.w,.. m.,P�mm.m wm.�.mN xa.YrnY...w.. rnpavmWryk.wWeeYbawmwrrvm Werw.b.+tlxY^^-PYtiv Y�gLL7nr/ran Y�Mwm�dle r10rnemwv�vv�..PwmlYe n.agnM..rund NYmnaaY am mvmaP.mMewurmeaanery.xep lu.Meinaree..w CYne��e�W ryp�eMb� an �YdNaimY�.tlFbpN�Nb�Yw wremYae CM^^.mmaNlnwrw.pb..e lmmeYiMYr�uw�.x�mem.IwlwYhpe�allM VMMP porenmYrs MM ebr�e.W �vY PomemrYNw Nrhnemuya n MJM tletl NwMYnolvYw..iYTareWo�YaYdIMmlWrlb.w..tlW WamaCtl.mm®+n. W.rtlM..�uredNrm..V>aM.MY.Y[Y�YrYMI1M.evn.+M.MMbrNaimw WY.W r:rpen�aiYil:.Ya`o®ibewx,'�enrbm.m�u�ww.wwr.rmYrYYw...rw.�urmwwarrm.w..vmrwe,..Pwronm. 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,521'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 8,730psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Mike Quick Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: July 14, 2019 N/A 6,521' Perforation Depth MD (ft): See Attached Schematic 6,521' 5,838'6-3/4" 16" 7-5/8" 120' 1,778' 2,980psi 6,890psi 120' 1,636' 120' 1,778' N/A TVD Burst N/A 10,600psi MDLength Size 20 AAC 25.055 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE, FEDA028142, FEDA028143 220-045 50-133-20689-00-00 Kenai Unit (KU) 42-12 Kenai Gas Field / Undefined Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic mquick@hilcorp.com 5,838' 5,820' 5,147' ~1327psi 5,820' ZXP Liner Pkr, N/A 1,636' MD / 1,526' TVD, N/A Perforation Depth TVD (ft): Tubing Size: Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:44 pm, Jun 30, 2020 320-280 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.30 13:28:38 -08'00' Taylor Wellman * Perforations shallower than 4,224' MD require a spacing exception per 20 AAC 25.055(a)(4). SFD 7/1/2020 * SFD 7/1/2020 DSR-6/30/2020VTL 7/7/20 10-404X Comm. 7/7/2020 dts 7/7/2020 Well Prognosis Well: KU 42-12 Date: 6-29-2020 Well Name: KU 42-12 API Number: 50-133-20689-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: July 14, 2020 Rig: N2 / E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 220-045 First Call Engineer: Michael Quick (907) 777-8442 (O) (907) 317-2969 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) AFE Number: 2011785C Maximum Expected BHP: ~ 1,327 psi @ 3,490’ TVD (Based on geotap side wall tool data) Max. Potential Surface Pressure: ~ 978 psi @ 3,490’ TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary KU 42-12 is a grass roots development well targeting gas sands in the Middle and Upper Beluga formations. This new well TD was reached on 6-2-2020. Hilcorp has been perforating the sands approved in Sundry 320-242, and has not yet found commercial hydrocarbons. The purpose of this work/sundry is to add perforations in the A7 Sterling sand. The Sterling A7 sand is above the boundary for the Sterling Gas Pool 3, and is in an undefined pool. This sand appears to exist locally around this well, and is not and has not been produced in any offset wells . This A7 sand will be operated under statewide spacing rules, and will be produced with no other perforations in the well – a spacing exception is therefore not required. The A7 sand was deleted from the Sundry 320-242 at Hilcorp’s request during processing. The purpose of this work/sundry is to push fluid away with N2, set a CIBP, and perforate the Sterling A7. Notes Regarding Wellbore Condition x Last perforation interval 5600’ to 5602’, brought in fill and water into well. Last slickline tag ~5513’, fluid level ~ 1302’. Safety Concerns x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. 2. RIH with GPT log to confirm fluid level and tag fill. 3. Rig up N2 and push fluid into perforations, push fluid level to ~5,510’. 4. RIH with 5-1/2” CIBP and set at +/-5,400’ to +/-5,500’ (depending on fill tag) s in an undefined pool. d is not and has not been produced in any offset wells . o add perforations in the A7 Sterling sand. Well Prognosis Well: KU 42-12 Date: 6-29-2020 5. Leave ~ 1500 psi N2 pressure on well and rig down N2. 6. PU and RIH W/perf guns. Perforate with 2-7/8” to 3-3/8” Perf guns 6 to 12 JSPF 60 degree phasing. If necessary, bleed N2 pressure down as requested by the OE to establish a drawdown on the formation. 7. Proposed Perforated Intervals: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom A7 ±4,190' ±4,230' 40' ±3,573' ±3,600' a. Proposed perfs. also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals post shot. f. This sand is within an Undefined Pool, and will follow statewide spacing rule. 8. POOH. 9. RD e-line. 10. Turn well over to production to test. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil tubing BOPE 4. Standard Well Procedure – N2 Operations Updated by DMA 06-29-20 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,820’ MD / TVD = 5,147’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Csg 17 L-80 CDC HTQ 4.892” Surf 6,521’ 1 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 5,820’ CIBP 6/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status UB 3 5,600 5,602' 4,932' 4,934' 2' 06/19/20 Open UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 Isolated 2 UB 5B UB 3 Updated by DMA 06-29-20 PROPOSED SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = 5,820’ MD / TVD = 5,147’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,778’ 5-1/2" Prod Csg 17 L-80 CDC HTQ 4.892” Surf 6,521’ 1 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,636’ 5-1/2” ZXP Liner Hanger Packer 2 ±5,400’ CIBP - ±5,400-±5,500 3 5,820’ CIBP 6/18/20 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A7 ±4,190 ±4,230 ±3,568' ±3,604' 40' Proposed TBD UB 3 5,600 5,602' 4,932' 4,934' 2' 06/19/20 Open UB 5B 5,853' 5,863' 5,180' 5,190' 10' 06/09/20 Isolated A7 2 3 UB 5B UB 3 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. 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: Initial Completion, CTCO/N2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,521'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 8,730psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Mike Quick Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: June 19, 2020 N/A ~6500 Perforation Depth MD (ft): See Attached Schematic ~6500 ~58076-3/4" 16" 7-5/8" ~120 1,787' 2,980psi 6,890psi ~120 1,643' ~120 1,787' N/A TVD Burst N/A 10,600psi MDLength Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE, FEDA028142, FEDA028143 220-045 50-133-20689-00-00 Kenai Unit (KU) 42-12 Kenai Gas Field / Beluga-Upper Tyonek Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic mquick@hilcorp.com 5,838'~6400 ~5709 ~1742psi N/A ZXP Liner Pkr, N/A ~1,550' MD / 1,457' TVD, N/A Perforation Depth TVD (ft): Tubing Size: Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:45 am, Jun 05, 2020 320-242 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.04 22:36:48 -08'00' Taylor Wellman DSR-6/8/2020 X Guy Schwartz 6-8-20CTU N2 *4000 psi BOPE Test (CT) CT 10-407* * Perforations shallower than 4,224' MD require a spacing exception. SFD 6/9/2020 SFD 6/9/2020 (final well report) gls 6/9/20 Comm 6/11/2020 dts 6/9/2020 JLC 6/10/2020 Well Prognosis Well: KU 42-12 Date: 6-3-2020 Well Name: KU 42-12 API Number: 50-133-20689-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: June 19, 2020 Rig: Coil Unit/ E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 220-045 First Call Engineer: Michael Quick (907) 777-8442 (O) (907) 317-2969 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) AFE Number: 2011785C Maximum Expected BHP: ~ 2,300 psi @ 5,578’ TVD (Based on geotap side wall tool data) Max. Potential Surface Pressure: ~ 1,742 psi @ 5,578’ TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary KU 24-32 is a grass roots development well targeting gas sands in the Middle and Upper Beluga formations. This new well TD was reached on 6-2-2020. The purpose of this work/sundry is to evaluate cement, jet the well dry with CT, and perforate. Notes Regarding Wellbore Condition x Well will be filled with 6% KCL x Rig cleaned out well to PBTD prior to rigging down. x IA (7-5/8” x 5-1/2” annulus) will be pressure tested to 2500 psi by drilling rig per PTD 220-045. x E-line will complete CBL prior to starting sundry work. Electronic copy of CBL to be sent to AOGCC when completed. Safety Concerns x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority Pre-Sundry Work 1. MIRU E-line unit. RU Stripping head. PU CBL. TIH to PBTD. Run CBL log from PBTD to 1500’ (liner top packer at ~1550’). 2. RDMO E-line unit. Submit CBL log to AOGCC. Coiled Tubing Procedure (Start of Sundry work) 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. 2. MU Jet nozzle. 3. RIH W/ nozzle. RU N2 pumping unit. 4. Drop ball and come online with N2 and jet well dry. a) Estimated volume of displaced 6% KCl is (+/-) 140 bbls. (Based on estimated PBTD of +/- 6,340’). 5. RIH w/ coiled tubing and jet nozzle BHA and tag PBTD. CBL (email to guy.schwartz@alaska.gov) Note: granted verbal approval 6/8/20 to rig up CT and blowdown well following CBL log gls CTU N2 FCO Well Prognosis Well: KU 42-12 Date: 6-3-2020 6. Once well is dry, leave ~1,300 psi. on the well for first perforation interval. 7. POOH w/ coil. LD BHA. 8. RDMO Coiled Tubing. E-Line Procedure 9. MIRU e-line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. Note that the well is pressurized with nitrogen. a) If necessary, bleed pressure down as requested by the OE to establish a drawdown on the formation. 10. PU RIH W/perf guns. Perforate each interval with 2-7/8” or 3-1/8” Perf guns 6 to 12 JSPF 60 degree phasing. 11. Proposed Perforated Intervals: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom A6 ±4,029' ±4,051' 22' ±3,422' ±3,444' A7 ±4,203' ±4,218' 15' ±3,580' ±3,595' A10 ±4,325' ±4,339' 14' ±3,691' ±3,705' A10 ±4,363' ±4,380' 17' ±3,727' ±3,744' A11 ±4,411' ±4,437' 26' ±3,773' ±3,799' B2 ±4,554' ±4,569' 15' ±3,909' ±3,924' UB 1X ±5,422' ±5,438' 16' ±4,759' ±4,775' UB 1 ±5,455' ±5,466' 11' ±4,790' ±4,801' UB 2 ±5,513' ±5,538' 25' ±4,847' ±4,872' UB 3 ±5,593' ±5,610' 17' ±4,925' ±4,942' UB 4 ±5,625' ±5,641' 16' ±4,956' ±4,972' UB 4 ±5,645' ±5,654' 9' ±4,975' ±4,984' UB 4B ±5,693' ±5,704' 11' ±5,023' ±5,034' UB 5A ±5,760' ±5,764' 4' ±5,089' ±5,093' UB 5B ±5,850' ±5,866' 16' ±5,177' ±5,193' UB 6 ±5,872' ±5,880' 8' ±5,199' ±5,207' UB 8 ±5,965' ±5,981' 16' ±5,289' ±5,305' UB 8 ±5,986' ±6,004' 18' ±5,310' ±5,328' UB 9 ±6,024' ±6,033' 9' ±5,347' ±5,356' MB 3 ±6,195' ±6,215' 20' ±5,516' ±5,536' MB 3 ±6,247' ±6,258' 11' ±5,567' ±5,578' a. Proposed perfs. also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals post shot. f. These sands are governed by Conservation Order 510A. New Perforations Per M. Quick, Hilcorp: Delete A6 & A7 perfs as they will require a spacing exception. SFD 6/9/2020 Well Prognosis Well: KU 42-12 Date: 6-3-2020 g. Sand intervals may be grouped or shot one at a time and flow tested to the system. If a sand makes water, then a plug or an isolation patch may be set prior to moving up to the next sand interval. E-line Procedure (Contingency) a. If any zone produces sand and/or water or needs isolation b. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. c. RIH and set 5-1/2” CIBP at depth above zone. Or d. RIH and set 5-1/2” Casing Patch across the zone. e. Jet dry with nitrogen if needed. 12. POOH. 13. RD e-line. 14. Turn well over to production to test. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil tubing BOPE 4. Standard Well Procedure – N2 Operations Updated by DMA 06-03-20 SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = ~6,400’ MD / TVD = ~5,709’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,787’ 5-1/2" Prod Csg 17 L-80 CDC HTQ 4.892” Surf ~6,521’ 1 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 ~1,550’ 5-1/2” ZXP Liner Hanger Packer OPEN HOLE / CEMENT DETAIL 7-5/8" 140 BBL’s of cement in 9-7/8” hole – Returns to surface (50% excess) 5-1/2” 75 BBL’s of cement in 6-3/4” hole. Est. TOC @ 1,250’ (5% excess) 6-3/4” hole MIT-IA to 2500 psi liner hanger CBL required Updated by DMA 06-03-20 PROPOSED SCHEMATIC Kenai Gas Field KU 42-12 PTD: 220-045 API: 50-133-20689-00-00 PBTD = ~6,400’ MD / TVD = ~5,709’ TD = 6,521’ MD / TVD = 5,838’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 DWC/C 6.875” Surf 1,787’ 5-1/2" Prod Csg 17 L-80 CDC HTQ 4.892” Surf ~6,521’ 1 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 ~1,550’ 5-1/2” ZXP Liner Hanger Packer OPEN HOLE / CEMENT DETAIL 7-5/8" 140 BBL’s of cement in 9-7/8” hole – Returns to surface (50% excess) 5-1/2” 75 BBL’s of cement in 6-3/4” hole. Est. TOC @ 1,250’ (5% excess) 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A6 ±4,029' ±4,051' ±3,422' ±3,444' 22' Proposed TBD A7 ±4,203' ±4,218' ±3,580' ±3,595' 15' Proposed TBD A10 ±4,325' ±4,339' ±3,691' ±3,705' 14' Proposed TBD ±4,363' ±4,380' ±3,727' ±3,744' 17' Proposed TBD A11 ±4,411' ±4,437' ±3,773' ±3,799' 26' Proposed TBD B2 ±4,554' ±4,569' ±3,909' ±3,924' 15' Proposed TBD UB 1X ±5,422' ±5,438' ±4,759' ±4,775' 16' Proposed TBD UB 1 ±5,455' ±5,466' ±4,790' ±4,801' 11' Proposed TBD UB 2 ±5,513' ±5,538' ±4,847' ±4,872' 25' Proposed TBD UB 3 ±5,593' ±5,610' ±4,925' ±4,942' 17' Proposed TBD UB 4 ±5,625' ±5,641' ±4,956' ±4,972' 16' Proposed TBD ±5,645' ±5,654' ±4,975' ±4,984' 9' Proposed TBD UB 4B ±5,693' ±5,704' ±5,023' ±5,034' 11' Proposed TBD UB 5A ±5,760' ±5,764' ±5,089' ±5,093' 4' Proposed TBD UB 5B ±5,850' ±5,866' ±5,177' ±5,193' 16' Proposed TBD UB 6 ±5,872' ±5,880' ±5,199' ±5,207' 8' Proposed TBD UB 8 ±5,965' ±5,981' ±5,289' ±5,305' 16' Proposed TBD ±5,986' ±6,004' ±5,310' ±5,328' 18' Proposed TBD UB 9 ±6,024' ±6,033' ±5,347' ±5,356' 9' Proposed TBD MB 3 ±6,195' ±6,215' ±5,516' ±5,536' 20' Proposed TBD ±6,247' ±6,258' ±5,567' ±5,578' 11' Proposed TBD A7 A10 UB 1 UB 4B UB 5A UB 5B UB 6 UB 8 UB 9 MB 3 UB 2 UB 3 UB 4 A11 B2 UB 1X A6 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. 1 Carlisle, Samantha J (CED) From:Mike Quick <mquick@hilcorp.com> Sent:Tuesday, June 9, 2020 1:59 PM To:Schwartz, Guy L (CED) Cc:Taylor Wellman; Ted Kramer; Donna Ambruz Subject:RE: KU 42-12 AOGCC 10-403 PTD 220-045 Submitted 06-05-20 - Sundry Application Attachments:KU 42-12 RCBL 6_9_2020.pdf Guy– AttachedistheCBLforKU42Ͳ12.Thecementbondlooksgreatoverallonthiswell. TOCpickedat~1710’ Goodcementbondfrom~2190’toTD. Thelinertoppackertopisat~1640’,andthe7Ͳ5/8”shoeisat~1778’. Pleaseletmeknowifyouwouldliketodiscuss. Thanks, Mike From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Monday,June8,202011:17AM To:MikeQuick<mquick@hilcorp.com> Cc:TaylorWellman<twellman@hilcorp.com>;TedKramer<tkramer@hilcorp.com>;DonnaAmbruz <dambruz@hilcorp.com> Subject:[EXTERNAL]RE:KU42Ͳ12AOGCC10Ͳ403PTD220Ͳ045Submitted06Ͳ05Ͳ20ͲSundryApplication Mike, YouhaveverbalapprovaltouseCTUandN2toblowdownKU42Ͳ12.TheCBLmustbesubmittedalsoassoonasitis loggedasyoustatedbelow. FullapprovalofthesundryandreviewoftheCBLisrequiredbeforethewellcanbeperforated. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From:MikeQuick<mquick@hilcorp.com> Sent:Monday,June8,202010:33AM 2 To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:TaylorWellman<twellman@hilcorp.com>;TedKramer<tkramer@hilcorp.com>;DonnaAmbruz <dambruz@hilcorp.com> Subject:KU42Ͳ12AOGCC10Ͳ403PTD220Ͳ045Submitted06Ͳ05Ͳ20ͲSundryApplication Guy– Aswediscussed,HilcorpisrequestingverbalapprovalfortheN2portionoftherecentlysubmittedsundryforKU42Ͳ12, toperformtheN2blowdownofthiswell,priortomovingthecoiltubingequipmenttothewestsideoftheinlet. WewillruntheCBLtomorrow,6/9,andwouldliketomoveintothecoiltubingandN2blowdownstartingon6/10. TheCBLlogwillbesubmittedonceitiscompleted.Hilcorpwillbereadytoperforatethewelloncethesundryis approved. Pleaseletmeknowifyouneedanyfurtherinformation. Thankyou, Mike From:Carlisle,SamanthaJ(CED)[mailto:samantha.carlisle@alaska.gov] Sent:Friday,June5,20209:46AM To:DonnaAmbruz<dambruz@hilcorp.com> Cc:MikeQuick<mquick@hilcorp.com>;TaylorWellman<twellman@hilcorp.com>;TedKramer<tkramer@hilcorp.com> Subject:[EXTERNAL]RE:KU42Ͳ12AOGCC10Ͳ403PTD220Ͳ045Submitted06Ͳ05Ͳ20ͲSundryApplication Received for processing From:DonnaAmbruz<dambruz@hilcorp.com> Sent:Friday,June5,20206:59AM To:AOGCCPermitting(CEDsponsored)<aogcc.permitting@alaska.gov> Cc:MikeQuick<mquick@hilcorp.com>;TaylorWellman<twellman@hilcorp.com>;TedKramer<tkramer@hilcorp.com> Subject:KU42Ͳ12AOGCC10Ͳ403PTD220Ͳ045Submitted06Ͳ05Ͳ20ͲSundryApplication ApplicationforSundryApproval Thankyou. Donna Ambruz Operations/RegulatoryTech KenaiAssetTeam HilcorpAlaska,LLC 3800CenterpointDrive,Suite1400 Anchorage,AK99503 907.777.8305ͲDirect 907.777.8510ͲFax dambruz@hilcorp.com STATE OF ALASKA jr� Reviewed By: OIL AND GAS CONSERVATION COMMISSION P. I. Supry q.JL&2,0 BOPE Test Report for: KENAI UNIT 42-12 / Comm Contractor/Rig No.: Hilcorp 169 PTD#: 2200450 ' DATE: 5/27/2020 - Inspector Austin McLeod Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Hauck/Riley Rig Rep: Davis/Lynch Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopSAM200528093827 Rams: Annular: Valves: MASP: Type Test: NIT 250/3500 - 250/3500 250/3500 1170, Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: Quantity ACCUMULATOR SYSTEM: Quantity P/F P/F P/F Visual Alarm I Time/Pressure P/F Location Gen.: P Trip Tank P P - System Pressure 3050_ P Housekeeping: P Pit Level Indicators P-_" P - Pressure After Closure _1600 P-' PTD On Location P Flow Indicator P P - 200 PSI Attained 22 P " Standing Order Posted P _" Meth Gas Detector -P- P Full Pressure Attained 90 -, P_ ' Well Sign P H2S Gas Detector FP FP ✓ Blind Switch Covers: All stations_" P Drl. Rig _P_' MS Misc - 0- NA Nitgn. Bottles (avg): 4(&,2487 - P Hazard Sec. P NA ACC Misc 0 NA Misc NA HCR Valves 2' 2-1/16"/3-1/8"- P FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Quantity P/F Quantity Size P/F Upper Kelly I P ' Stripper _0 P NA Lower Kelly l P Annular Preventer 1 11" P_ -- Ball Type I ' P -" #1 Rams --1 , 2-7/8"x5"_" P- _ Inside BOP I P #2 Rams 1 - Blinds P " FSV Misc 0 NA #3 Rams 1 - 2-7/8"x5" P #4 Rams - 0 -NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1- 3-1/8" P HCR Valves 2' 2-1/16"/3-1/8"- P Kill Line Valves 2 ' 2-1/16" P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 2 ./ Test Results Remarks: 4-1/2" joint. Shaker H2S needed calibrated. Passed retest. Good test. CHOKE MANIFOLD: Quantity P/F No. Valves 15 P . Manual Chokes 1 P Hydraulic Chokes I P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Test Time 5 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Beluga/Upper Tyonek Gas Pool, KU 42-12 Hilcorp Alaska, LLC Permit to Drill Number: 220-045 Surface Location: 284’ FSL, 1157’ FWL, SEC. 6, T4N, R11W, SM, AK Bottomhole Location: 1781’ FNL, 164’ FEL, SEC. 12, T4N, R12W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of May, 2020. y, JMPi 19 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 6,500' TVD: 5,807' 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 83' 15. Distance to Nearest Well Open Surface: x-272070 y- 2362338 Zone-4 65' to Same Pool: 1230' to KBU 11-07 16. Deviated wells:Kickoff depth: 250 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 38.5 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' 9-7/8" 7-5/8" 29.7# L-80 DWC/C 1,750' Surface Surface 1,750' 1,608' 6-3/4" 5-1/2" 17# L-80 CDC HTQ 6,500' Surface Surface 6,500' 5,807' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned?Yes No 20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:50- Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Sr Pet Eng Sr Pet Geo Sr Res Eng 5496' to nearest unit boundary 5/21/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Monty Myers mmyers@hilcorp.com 777-8431 18. Casing Program:Top - Setting Depth - BottomSpecifications KU 42-12 Kenai Gas Field Beluga/ Upper Tyonek Gas Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 284’ FSL, 1157’ FWL, Sec 6, T4N, R11W, SM, AK FEE A028142, A028143 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 489 ft3 1170 1375' FNL, 68' FWL, Sec 7, T4N, R11W, SM, AK 1781' FNL, 164' FEL, Sec 12, T4N, R12W, SM, AK N/A 3271 1453 Total Depth MD (ft):Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Driven L - 675 ft3 / T - 209 ft3 Effect. Depth TVD (ft): Conductor/Structural Length Production Liner Casing Intermediate Commission Use Only Effect. Depth MD (ft): Authorized Signature: See cover letter for other requirements. Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): 5/7/2020 es N ype of W L l R L 1b S Class: os N es No s N o D s s s D 84 o : well is p G S S 20 S S S es No s No S G E S es No s Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.05.08 10:11:23 -08'00' Monty M Myers By Samantha Carlisle at 10:55 am, May 08, 2020 2200450 50-133-20689-00-00 SFD 5/8/2020 DSR-5/11/2020 Development - Gas *3500 psi BOPE test *Diverter Waived per 20 AAC 25.035 (h)(2) * CBL and MIT-IA to 2500 psi required. gls 5/18/20 *Separate sundry required to perforate well S00 yq p 5/19/2020 KU 42-12 Drilling Program Kenai Gas Field Rev 0 May 5th, 2020 KU 42-12 Drilling Procedure Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program:...................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 R/U and Preparatory Work ..................................................................................................... 10 10.0 N/U 16” Conductor Riser ........................................................................................................ 11 11.0 Drill 9-7/8” Hole Section .......................................................................................................... 13 12.0 Run 7-5/8” Surface Casing ...................................................................................................... 16 13.0 Cement 7-5/8” Surface Casing ................................................................................................. 19 14.0 BOP N/U and Test.................................................................................................................... 22 15.0 Drill 6-3/4” Hole Section .......................................................................................................... 23 16.0 Run 5-1/2” Production Casing ................................................................................................. 27 17.0 Cement 5-1/2” Production Casing ........................................................................................... 30 18.0 RDMO ...................................................................................................................................... 32 19.0 BOP Schematic ........................................................................................................................ 33 20.0 Wellhead Schematic ................................................................................................................. 34 21.0 Days Vs Depth .......................................................................................................................... 35 22.0 Geo-Prog .................................................................................................................................. 36 23.0 Anticipated Drilling Hazards .................................................................................................. 37 24.0 Hilcorp Rig 169 Layout ........................................................................................................... 39 25.0 FIT Procedure .......................................................................................................................... 40 26.0 Choke Manifold Schematic ...................................................................................................... 41 27.0 Casing Design Information ...................................................................................................... 42 28.0 6-3/4” Hole Section MASP ....................................................................................................... 43 29.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 44 30.0 Surface Plat (NAD 27) ............................................................................................................. 45 31.0 Directional Plan (wp06) ........................................................................................................... 47 Page 2 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 1.0 Well Summary Well KU 42-12 Pad & Old Well Designation KU 42-12 is a grass roots well on KGF Pad 14-06 Planned Completion Type 5-1/2” Production Longstring (monobore) Target Reservoir(s) Beluga Planned Well TD, MD / TVD 6,500 MD / 5,808’ TVD PBTD, MD / TVD 6,400’ MD / 5,709’ TVD Surface Location (Governmental) 284’ FSL, 1157’ FWL, Sec 6, T4N, R11W, SM, AK Surface Location (NAD 27) X=272070.17 Y=2362338.47 Surface Location (NAD 83) Top of Productive Horizon (Governmental) 1375’ FNL, 68’ F WL, Sec 7, T4N, R11W, SM, AK TPH Location (NAD 27) X=271033.73, Y=2360599.81 TPH Location (NAD 83) BHL (Governmental) 1781’ FNL, 164’ F EL, Sec 12, T4N, R12W, SM, AK BHL (NAD 27) X=270794.3, Y=2360198.13 BHL (NAD 83) AFE Number 2011785 (D, C, F) AFE Drilling Days 3 MOB, 21 DRLG AFE Completion Days AFE Drilling Amount $2,258,160 AFE Completion Amount $1,226,984 Maximum Anticipated Pressure (Surface) 1170 psi Maximum Anticipated Pressure (Downhole/Reservoir) 1453 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB – GL 81.6’(63.6 + 18) Ground Elevation 63.6’ BOP Equipment 11” 5M Control Tech Type 90 Annular BOP 11” 5M Control Tech Type 82 Double Ram 11” 5M Control Tech Type 82 Single Ram Page 3 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 2.0 Management of Change Information Page 4 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 16” 15.01” 14.822 17” 84 J-55 Weld 2980 1410 - 9-7/8” 7-5/8” 6.875” 6.75” 8.5” 29.7 L-80 BTC 6890 4790 683 6-3/4” 5-1/2” 4.892” 4.767” 6.05” 17 P110HC USS-CDC 10600 8730 568 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) All 4-1/2” 3.826 2.6875” 5.25” 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 5 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp.com and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting x Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don’t wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Matt Hogge: O: (907) 777-8418 C: (907) 227-9829 2. Spills: Keegan Fleming: O:907-777-8477 C:907-350-9439 x Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1368 x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cmt report x Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp.com Page 6 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 6.0 Planned Wellbore Schematic MIT-IA to 2500 psi Swell packer CBL required. Page 7 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 7.0 Drilling / Completion Summary KU 42-12 is an S-shaped directional grassroots development well to be drilled off of the KGF 14-06 pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development in the Middle and Upper Beluga sands. The base plan is a directional wellbore with a kick off point at 250’ MD. Maximum hole angle will be 39 deg. and TD of the well will be 6,500’ TMD/ 5808’ TVD, ending with 10 deg inclination left in the hole. Vertical section will be 4679 ft. Drilling operations are expected to commence approximately May 21st 2020. The Hilcorp Rig # 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 1,750 MD / 1,608’ TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 – 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. General sequence of operations: 1. MOB Hilcorp Rig # 169 to well site 2. N/U conductor riser. (No diverter, diverter waiver requested) 3. Drill 9-7/8” hole to 1,750’ MD. Run and cmt 7-5/8” surface casing. 4. ND conductor riser, N/U & test 11” x 5M BOP. 5. Drill 6-3/4” hole section to 6,500’ MD. Perform Wiper trip. 6. Make cleanout run 7. POOH laying down drill pipe. 8. Run and cmt 5-1/2” production casing. 9. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR + Res 2. Production Hole: GR + Res 3. Mud loggers from surface casing point to TD. Drilling operations are expected to commence approximately May 21st 2020. The Ht (No diverter, diverter waiver requested)Diverter Waiver approved. gls Page 8 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling of KU 42-12. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements” x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Regulation Variance Requests: x Diverter waiver request requested due to the recent drilling of KU 11-07X and KU 24-32 on a nearby pad. No issues were experienced on either well drilling the surface hole. Surface casing will be set at the same depth on KU 42-12. No shallow hydrocarbon zones will be penetrated. Diverter waiver request r Page 9 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 9-7/8” x No diverter utilized n/a 6-3/4” x 11” x 5M Annular BOP x 11” x 5M Double Ram o Blind ram in btm cavity x Mud cross x 11” x 5M Single Ram x 3-1/8” 5M Choke Line x 2-1/16” x 5M Kill line x 3-1/8” x 2-1/16” 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3500 (Annular 2500 psi) Subsequent Tests: 250/3500 (Annular 2500 psi) x Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). x Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (O): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 9.0 R/U and Preparatory Work 9.1 Set 16” conductor at +/-120’ below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4” 3M “A” section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Hilcorp Rig # 169, spot service company shacks, spot & R/U company man & toolpusher offices. 9.7 RU Mud loggers on surface hole section for gas detection only. No samples required 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 9-7/8” hole section. 9.10 Install 5-1/2” liners in mud pumps. x HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 strokes with 5-1/2” liners. U Mud loggers on surface hole section for gas detection only. Page 11 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 10.0 N/U 16” Conductor Riser 10.1 N/U 16” Conductor Riser x Ensure line does not direct flow from trip tank straight down the flowline. Fill up line and flowline should be oriented 90 degrees to each other at approx. the same height. x Ensure flowline outlet installed so that enough slope exists to carry cuttings to the shakers. x Consider adding additional drainage points at the bottom of the conductor riser if deemed necessary. x R/U fill up line to conductor riser. 10.2 Set wearbushing in wellhead. Diverter is waived per 20 AAC 25.035 (h)(2) Page 12 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 10.3 Rig Orientation on KGF 14-06 pad: Page 13 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 11.0 Drill 9-7/8” Hole Section 11.1 P/U 9-7/8” directional drilling assy: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Workstring will be 4.5” 16.6# S-135 CDS40 11.2 Primary Bit: Page 14 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 11.3 4-1/2” Workstring & HWDP will come from Hilcorp. Jars will come from Weatherford. 11.4 Begin drilling out from 16” conductor at reduced flow rates to avoid broaching the conductor. 11.5 Drill 9-7/8” hole section to 1,750’ MD/ 1,608’ TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. x Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. x Keep swab and surge pressures low when tripping. x Make wiper trips every 500’ or every couple days unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. x TD the hole section in a good shale between 1700’ MD and 1800’ MD. x Take MWD surveys every stand drilled (60’ intervals). 11.6 9-7/8” hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-1750’ 8.8 – 9.5 85-150 20 - 40 25 - 45 <10 8.5-9.0 8.8 – 9.5 Page 15 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 System Formulation: Aquagel + FW spud mud Product Concentration FRESH WATER SODA ASH AQUAGEL CAUSTIC SODA BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G X-TEND II 0.905 bbl 0.5 ppb 12-15 ppb 0.1 ppb (9 pH) as needed as required for weight if required for <12 FL 0.1 ppb 0.02 ppb 11.7 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16” conductor shoe. 11.8 TOH with the drilling assy, handle BHA as appropriate. Page 16 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 12.0 Run 7-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 7-5/8” casing running equipment. x Ensure 7-5/8” BTC x CDS 40 XO on rig floor and M/U to FOSV. x R/U fill-up line to fill casing while running. x Ensure all casing has been drifted on the location prior to running. x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ float shoe bucked on (thread locked). x (1) Joint with coupling thread locked. x (1) Joint with float collar bucked on pin end & thread locked. x Install (2) centralizers on shoe joint over a stop collar. 10’ from each end. x Install (1) centralizer, mid tube on thread locked joint and on FC joint. x Ensure proper operation of float equipment. 12.5 Continue running 7-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. x After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. x Install (1) centralizer every other joint to 300’. Do not run any centralizers above 300’ in the event a top out job is needed. x Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8” DWC/C M/U Torque Casing OD Min Torque Max Torque 7-5/8” 21,700 ft-lbs 25,100 ft-lbs (surface casing ) Page 17 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 Page 18 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 13.0 Cement 7-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 75% open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 16” Conductor x 7-5/8” casing annulus: 120’ x .0932 bpf = 11.2 63 12.0 ppg LEAD: 9-7/8” OH x 7-5/8” Casing annulus: (1750’ – 120’) x .0382 bpf x 1.75 = 109 612 Total LEAD: 120.2 675 ft3 15.4 ppg TAIL: 9-7/8” OH x 7-5/8” Casing annulus: (1750’-1250’) x .0382 bpf x 1.75 = 33.4 188 15.4 ppg TAIL: 7-5/8” Shoe track: 80 x .04591 bpf = 3.7 21 Total TAIL: 37.1 bbl 209 ft3 274 sx 171 sx Page 20 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 Cement Slurry Design: 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 1750’- 80’ = 1670’ x .04591 bpf = 77 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. Lead Slurry (1000’ MD to surface) Tail Slurry (1250’ to 1750’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Additives Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC S002 CaCl2 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaCl2 0.1 % BWOC 2.46 ft3/sk 1.22 ft3/s p 1750’- 80’ = 1670’ x .04591 bpf = 77 bbls Page 21 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 13.13 Do not overdisplace by more than ½ shoe track volume. Total volume in shoe track is 3.7 bbls. x Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 – 18 hours after CIP. x Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5”. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 14.0 BOP N/U and Test 14.1 N/U multi-bowl wellhead assy. Install 7-5/8” packoff P-seals. Test to 3000 psi. 14.2 N/U 11” x 5M BOP as follows: x BOP configuration from Top down: 11” x 5M annular BOP/11” x 5M double ram /11” x 5M mud cross/11” x 5M single ram x Double ram should be dressed with 2-7/8” X 5” variable bore rams in top cavity, blind ram in btm cavity. x Single ram should be dressed with 2-7/8” X 5” variable bore rams x N/U bell nipple, install flowline. x Install (2) manual valves & a check valve on kill side of mud cross. x Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.3 Run 4-1/2” BOP test assy, land out test plug (if not installed previously). x Test BOP to 250/3500 psi for 5/10 min. Test annular to 250/2500 psi for 5/10 min. x Ensure to leave “B” section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.4 R/D BOP test assy. 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 9.0 ppg 6% KCL PHPA mud system. 14.7 R/U mud loggers for production hole section. 14.8 Rack back as much 4-1/2” DP in derrick as possible to be used while drilling the hole section. Initial BOPE test Page 23 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 15.0 Drill 6-3/4” Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray and Resistivity LWD functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.7 Workstring will be 4-1/2” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. Page 24 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 15.8 Primary Bit: Page 25 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 15.9 6-3/4” hole section mud program summary: Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 1,750’- 6,500’ 9.0 – 10.0 40-53 15-25 15-25 8.5-9.5 11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.10 TIH w/ 6-3/4” directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 7-5/8” burst is 6890 psi / 2 = 3445 psi. 15.12 Drill out shoe track and 20’ of new formation. 15.13 CBU and condition mud for FIT. 9.0 – 10.0 – g R/U and test casing to 3500 psi / 30 min. 75/8"test Page 26 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 15.14 Conduct FIT to 13.5 ppg EMW. Note: Offset field test data predicts frac gradient at the 7-5/8” shoe to be between 11 - 13 ppg EMW. A 13.5 ppg FIT results in a 4 ppg kick margin while drilling with the planned MW of 9.5 ppg. Kick tolerance = (13.5-9.5)X(1608/5808) = 1.10 15.15 Drill 6-3/4” hole section to 6,500’ MD / 5,808’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 225 - 300 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. x Make wiper trips every 500’ unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Take (3) sets of formation samples every 20’. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8” shoe. 15.17 TOH with the drilling assy, standing back drill pipe. 15.18 LD BHA 15.19 RD loggers, PU 6-3/4”clean out BHA, and TIH to TD. 15.20 Pump sweep, CBU and condition mud for casing run. 15.21 POOH LDDP and BHA 15.22 Install 5-1/2” pipe rams in BOP stack and test. Kick tolerance = (13.5-9.5)X(1608/5808) = 1.10 Conduct FIT to 13.5 ppg EMW.FIT Page 27 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 16.0 Run 5-1/2” Production Casing 16.1. R/U Weatherford 5-1/2” casing running equipment. x Ensure 5-1/2” CDC HTQ x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill casing while running. x Ensure all casing has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). x Solid body centralizers will be pre-installed on shoe joint an FC joint. x Leave centralizers free floating so that they can slide up and down the joint. x Ensure proper operation of float shoe and float collar. x Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2” production casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install solid body centralizers on every joint across zones of interest, TBD after LWD. x Install solid body centralizers on every other joint to 7-5/8” shoe. Leave the centralizers free floating. x Pick up swell packer and place in string at approximately 1400’. 16.5. Continue running 5-1/2” production casing 5-1/2” CDC HTQ M/U torques Casing OD Minimum Maximum Yield Torque 5-1/2” 8,500 ft-lbs 11,500 ft-lbs 13,900 ft-lbs Page 28 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 Page 29 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 16.6. Run in hole w/ 5-1/2” casing to the 7-5/8” casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/ casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 5-1/2” X 6-3/4” swell packer to be placed at approximately 1400’. Swell packer should have 10’ handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5’ off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. PU 5-1/2” X 6-3/4” swell packer to be placed at approximately 1400’ Page 30 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 17.0 Cement 5-1/2” Production Casing 17.1. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 12.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 5% OH excess. Section: Calculation: Vol (BBLS) Vol (ft3) 7-5/8” x 5-1/2” Csg Overlap: 500’ x 0.01653 = 8 46 6-3/4” OH x 5-1/2” Casing: (6500 – 1750) x 0.01487 x 1.05 = 75 422 Shoe Track: 80’ x 0.04591 = 3.7 21 Total Volume : 87 489 400 sx Page 31 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 17.7. Drop wiper plug and displace with 6% KCl mud. 17.8. If hole conditions allow – continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than ½ shoe track. Shoe track volume is 1.5 bbls. 17.12. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours, test casing to 2500 psi and chart for 30 minutes. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 32 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Hilcorp Rig #169 NOTE: CBL over 5.5 " casing required. and MIT-IA to 2500 psi . Separate sundry to perforate the well is needed.******* Page 33 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 19.0 BOP Schematic Page 34 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 20.0 Wellhead Schematic Page 35 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 21.0 Days Vs Depth Page 36 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 22.0 Geo-Prog 5/7/2020 14:06 Well Name:KU 42-12 Survey Type RKB Field Name:Kenai Gas Field Surface Hole:83 Pool Name: Bottom Hole: 169 State:Alaska 18 Field Location:Onshore Coord Ref Sys:NAD27 AK Zone 4 65 County/Parish:Kenai Penninsula Borough Objective: Reference Plan: P3_A4 Sandstone Water 3857 3,228.0 -3210 2360677.16 271099.33 1445 0.45 P3_A8 Sandstone Gas/Water 4217 3,549.0 -3531 2360529.68 271028.01 947 0.27 P3_A9 Sandstone Gas/Water 4266 3,595.0 -3577 2360513.96 271020.41 1610 0.45 P3_A10 Sandstone Gas/Water 4289 3,616.0 -3598 2360506.86 271016.97 1005 0.28 P3_A11 Sandstone Gas/Water 4370 3,693.0 -3675 2360483.34 271005.6 1000 0.27 P4_B1 Sandstone Gas/Water 4452 3,771.0 -3753 2360461.64 270995.1 1623 0.43 P6_C1 Sandstone Gas/Water 5132 4,437.0 -4419 2360339.38 270935.97 250 0.06 P6_C2 Sandstone Gas/Water 5283 4,586.0 -4568 2360315.76 270924.55 250 0.05 U_BELUGA Sandstone Gas/Water 5355 4,656.0 -4638 2360304.59 270919.15 1526 0.33 UB_3 Sandstone Gas/Water 5518 4,816.0 -4798 2360279.12 270906.83 1875 0.39 UB_4 Sandstone Gas/Water 5592 4,889.0 -4871 2360267.55 270901.23 2008 0.41 UB_4A Sandstone Gas/Water 5625 4,922.0 -4904 2360262.31 270898.7 2088 0.43 UB_5B Sandstone Gas/Water 5745 5,041.0 -5023 2360243.52 270889.61 1329 0.26 UB_7 Sandstone Gas/Water 5823 5,117.0 -5099 2360231.41 270883.75 1008 0.20 UB_7A Sandstone Gas/Water 5851 5,145.0 -5127 2360227.01 270881.63 1457 0.28 UB_8 Sandstone Gas/Water 5903 5,196.0 -5178 2360218.89 270877.7 2135 0.41 M_BELUGA Sandstone Gas/Water 6021 5,312.0 -5294 2360200.46 270868.79 2147 0.41 MB_2 Sandstone Gas/Water 6106 5,396.0 -5378 2360187.05 270862.3 2258 0.42 MB_3 Sandstone Gas/Water 6191 5,480.0 -5462 2360173.78 270855.88 2370 0.43 MB_6 Sandstone Gas/Water 6456 5,741.0 -5723 2360132.34 270835.84 1802 0.31 TD Sandstone Gas/Water 6500 5,808.0 -5724 2360199.07 270794.86 1800 0.31 = Reservoir Objectives = Possible Geo Hazards TARGET RADIUS Mud Logging: LWD Data: Other Log Data: Coreing: Frac Half-Length SH Max Direction Surf. Inter. Prod. NOTES: DATA COLLECTION REQUIREMENTS: LWD Triple Combo; GeoTap Pressure Stations PROSED PIPE SET DEPTHS Chance of Success & Anticipated Rate ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE Target the Sterling and Beluga formations for offtake in whitespace on the south west side of KGF COMPLETION TYPE Monobore Fault Constraints 100 FT Surface casing to total depth, 30 ft samples with 20' samples in zones of interest, two sets of dry cut cuttings, chromatograph, show reports, pixler plots. Hagrid's Hut wp03ANTICIPATED FORMATION TOPS & GEOHAZARDS Geo Summary/ Justification: Several shows in 43-12, previous offtake in sterling, 11-07X shows remaining pressure and targets within Upper Beluga sands. Huge seismic amplitude in Sterling Interval. TOP NAME LITHOLOGY EXPECTED FLUID MD (FT) TVD (FT) TVDSS (FT)NORTHING EASTING Est. Pressure Gradient Ground Elevation: GEOLOGICAL PROGNOSIS Proposed x = 2,362,338.47 y = 272,070.17 TVD Ref Datum: TVD Ref Elevation: Planned Rig: Rig Height: x = 2,360,199.08 y = 270,794.86 6,500' MD 5,807' TVD Page 37 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 23.0 Anticipated Drilling Hazards 9-7/8” Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP between 25 – 45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of ~50 - ~60 lbs/100ft2 to combat this issue. Maintain low flow rates for the initial 200’ of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 –30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 38 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 6-3/4” Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 39 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 24.0 Hilcorp Rig 169 Layout Page 40 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 41 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 26.0 Choke Manifold Schematic Page 42 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 27.0 Casing Design Information 9-7/8"Mud Density:8.8 ppg 6-3/4"Mud Density:10 ppg Mud Density: 1453 psi (see attached MASP determination & calculation) 1130 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.45 psi/ft) and the casing evacuated for the internal stress 1234 7-5/8" 5-1/2" 00 00 1,750 6,500 1,608 5,808 1,750 6,500 29.7 17 L-80 L-80 DWC CDC HTQ 51,975 110,500 51,975 110,500 683 428 13.14 3.87 699 2,526 4,790 6,290 6.85 2.49 475 1,453 6,890 7,740 14.51 5.33Worst case safety factor (Burst) DATE: 05/07/2020 WELL: KU 42-12 FIELD: Kenai Gas Field DESIGN BY: Monty M Myers Hole Size Hole Size Hole Size MASP: Production Mode Casing Section MASP: Drilling Mode MASP: Length Top (TVD) Minimum Yield (psi) Weight (ppf) Grade Connection Weight w/o Bouyancy Factor (lbs) Min strength Tension (1000 lbs) Collapse Resistance w/o tension (Psi) Worst Case Safety Factor (Collapse) MASP (psi) Worst Case Safety Factor (Tension) Collapse Pressure at bottom (Psi) Calculation & Casing Design Factors Kenai Gas Field Calculation/Specification Casing OD Bottom (MD) Bottom (TVD) Top (MD) Tension at Top of Section (lbs) Design Criteria: 13.14 3.87 6.85 2.49 14.51 5.33 Page 43 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 28.0 6-3/4” Hole Section MASP MD TVD Planned Top: 0 0 Planned TD: 6500 5808 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad P3_A4 3228 1444.5 Water 8.6 0.45 P3_A8 3549 947 Gas/Water 5.1 0.27 P3_A9 3595 1609.65 Gas/Water 8.6 0.45 P3_A10 3616 1005 Gas/Water 5.3 0.28 P3_A11 3693 1000 Gas/Water 5.2 0.27 P4_B1 3771 1623 Gas/Water 8.3 0.43 P6_C1 4437 250 Gas/Water 1.1 0.06 P6_C2 4586 250 Gas/Water 1.0 0.05 U_BELUGA 4656 1526 Gas/Water 6.3 0.33 UB_3 4816 1875 Gas/Water 7.5 0.39 UB_4 4889 2008 Gas/Water 7.9 0.41 UB_4A 4922 2088 Gas/Water 8.2 0.42 UB_5B 5041 1329 Gas/Water 5.1 0.26 UB_7 5117 1008 Gas/Water 3.8 0.20 UB_7A 5145 1457 Gas/Water 5.4 0.28 UB_8 5196 2135 Gas/Water 7.9 0.41 M_BELUGA 5312 2147 Gas/Water 7.8 0.40 MB_2 5396 2258 Gas/Water 8.0 0.42 MB_3 5480 2370 Gas/Water 8.3 0.43 MB_6 5741 1802 Gas/Water 6.0 0.31 TD 6500 1800 Gas/Water 5.3 0.28 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date KBU 11-17X 9 - 9.2 1,587 5,464 2009 KBU 14-08 9 - 9.2 1,510 5,432 2008 KBU 41-18X 9 - 9.2 1,500 5,391 2008 KBU 24-7X 9 - 9.7 1,502 5,326 2006 KBU 32-08 9.3 - 9.8 1,446 5,401 2014 KBU 43-07Y 9.5 - 9.7 1,540 5,738 2014 Assumptions: 1. Fracture gradient at shoe (1608' TVD) is estimated at 17 ppg based on field test data. 2. Maximum planned mud density for the 6-3/4" hole section is 10.0 ppg. 3. Calculations assume "Unknown" reservoir contains 100% gas (worst case). 4. Calculations assume worst case event is 100% evacuation of wellbore to gas. Fracture Pressure at 7-5/8" shoe considering a full column of gas from shoe to surface: TVD Frac Grad 1608 ft X 0.884 psi/ft 1421 psi 1421(psi) - [0.1(psi/ft)*1608(ft)]= 1261 psi MASP from pore pressure during production mode (Complete evacuation to gas) 3228 ft X 0.450 psi/ft 1453 psi Downhol e 1453(psi) - [0.1(psi/ft)* 3228 (ft)]= 1130 psi Surface Summary: 1. MASP while drilling 6-3/4" production hole is governed by pore pressure from reservoir with entire wellbore evacuated to gas KU 42-12 Kenai Gas Field 6-3/4" Hole Section Maximum Anticipated Surface Pressure Calculation Formation TVD Est Pressure Oil/Gas/Wet PPG Grad P3_A4 3228 1444.5 Water 8.6 0.45 used to calculate the MASP Page 44 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 29.0 Spider Plot (NAD 27) (Governmental Sections) KU 42-12 Page 45 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 30.0 Surface Plat (NAD 27) Page 46 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 Page 47 Version 0 May, 2020 KU 42-12 Drilling Procedure Rev 0 31.0 Directional Plan (wp06) !""# $% $% -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500True Vertical Depth (1000 usft/in)-500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Vertical Section at 209.70° (1000 usft/in) Hagrid's Hutt wp06 20" 7 5/8" x 9 7/8" 5-1/2" x 6 3/4" 5 0 0 1 0 0 0 150020002500300035004 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 5 0 0 KU 42-12 wp06 Start Dir 3º/100' : 250' MD, 250'TVD End Dir : 1535.28' MD, 1440.44' TVD Start Dir 3º/100' : 3705.86' MD, 3137.77'TVD Start Dir 2º/100' : 4324.47' MD, 3675'TVD End Dir : 4824.47' MD, 4157.35' TVD Total Depth : 6500' MD, 5807.42' TVD P3_A4 P3_A8 P3_A9P3_A10 P3_A11 P4_B1 P6_C1 P6_C2 U_BELUGA UB_3 UB_4 UB_4A UB_5B UB_7 UB_7AUB_8 M_BELUGA MB_2 MB_3 MB_6 Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Pedal Curve Warning Method: Error Ratio WELL DETAILS: Plan: KU 42-12 65.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2362338.47 272070.17 60° 27' 36.933 N 151° 15' 45.889 W SURVEY PROGRAM Date: 2020-04-28T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 1750.00 KU 42-12 wp06 (KU 42-12) 3_MWD+IFR1+MS+Sag 1750.00 6500.00 KU 42-12 wp06 (KU 42-12) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 3293.00 3210.00 3897.06 P3_A4 3614.00 3531.00 4259.14 P3_A8 3660.00 3577.00 4308.49 P3_A9 3681.00 3598.00 4330.86 P3_A10 3758.00 3675.00 4412.32 P3_A11 3836.00 3753.00 4494.08 P4_B1 4502.00 4419.00 5174.44 P6_C1 4651.00 4568.00 5325.74 P6_C2 4721.00 4638.00 5396.82 U_BELUGA 4881.00 4798.00 5559.29 UB_3 4954.00 4871.00 5633.41 UB_4 4987.00 4904.00 5666.92 UB_4A 5106.00 5023.00 5787.76 UB_5B 5182.00 5099.00 5864.93 UB_7 5210.00 5127.00 5893.36 UB_7A 5261.00 5178.00 5945.15 UB_8 5377.00 5294.00 6062.94 M_BELUGA 5461.00 5378.00 6148.23 MB_2 5545.00 5462.00 6233.53 MB_3 5806.00 5723.00 6498.56 MB_6 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: KU 42-12, True North Vertical (TVD) Reference:As-Built RKB @ 83.00usft Measured Depth Reference: As-Built RKB @ 83.00usft Calculation Method:Minimum Curvature Project:Kenai Gas FieldSite:KGF 14-6 Pad Well:Plan: KU 42-12 Wellbore:KU 42-12 Design:KU 42-12 wp06 Kenai Gas Field KGF 14-6 Pad Plan: KU 42-12 KU 42-12 KU 42-12 wp06 5.388 CASING DETAILS TVD TVDSS MD Size Name 120.00 37.00 120.00 20 20" 1608.34 1525.34 1750.00 7-5/8 7 5/8" x 9 7/8" 5807.42 5724.42 6500.00 5-1/2 5-1/2" x 6 3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 3 1535.28 38.56 209.70 1440.44 -361.70 -206.32 3.00 209.70 416.40 End Dir : 1535.28' MD, 1440.44' TVD 4 3705.86 38.56 209.70 3137.77 -1536.90 -876.67 0.00 0.00 1769.35 Start Dir 3º/100' : 3705.86' MD, 3137.77'TVD 5 4324.47 20.00 209.70 3675.00 -1798.54 -1025.92 3.00 -180.00 2070.57 Hagrid's Hutt wp06 Start Dir 2º/100' : 4324.47' MD, 3675'TVD 6 4824.47 10.00 209.70 4157.35 -1910.81 -1089.95 2.00 180.00 2199.82 End Dir : 4824.47' MD, 4157.35' TVD 7 6500.00 10.00 209.70 5807.42 -2163.54 -1234.11 0.00 0.00 2490.77 Total Depth : 6500' MD, 5807.42' TVD -2250 -2100 -1950 -1800 -1650 -1500 -1350 -1200 -1050 -900 -750 -600 -450 -300 -150 0 150 South(-)/North(+) (300 usft/in)-1800 -1650 -1500 -1350 -1200 -1050 -900 -750 -600 -450 -300 -150 0 150 300 West(-)/East(+) (300 usft/in) Hagrid's Hutt wp06 20" 7 5/8" x 9 7/8" 5-1/2" x 6 3/4" 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4500 5000 5500 5807 KU 42-12 wp06 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 3º/100' : 3705.86' MD, 3137.77'TVD Start Dir 2º/100' : 4324.47' MD, 3675'TVD End Dir : 4824.47' MD, 4157.35' TVD Total Depth : 6500' MD, 5807.42' TVD CASING DETAILS TVD TVDSS MD Size Name 120.00 37.00 120.00 20 20" 1608.34 1525.34 1750.00 7-5/8 7 5/8" x 9 7/8" 5807.42 5724.42 6500.00 5-1/2 5-1/2" x 6 3/4" Project: Kenai Gas Field Site: KGF 14-6 Pad Well: Plan: KU 42-12 Wellbore: KU 42-12 Plan: KU 42-12 wp06 WELL DETAILS: Plan: KU 42-12 65.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2362338.47 272070.17 60° 27' 36.933 N 151° 15' 45.889 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: KU 42-12, True North Vertical (TVD) Reference:As-Built RKB @ 83.00usft Measured Depth Reference:As-Built RKB @ 83.00usft Calculation Method:Minimum Curvature -2400 -2133 -1867 -1600 -1333 -1067 -800 -533 -267 0 267 533 800 1067 1333 South(-)/North(+) (400 usft/in)-1600 -1333 -1067 -800 -533 -267 0 267 533 800 1067 West(-)/East(+) (400 usft/in) 5 0 0 1 0 0 0 1 5 0 0 2 0 0 0 2500 3 000 35 0 0 4000 4 5 0 0 5 0 0 0550060006500 700075007615KBU 11-075001000150020002 5 0 0300 0 35004 0 0 0 4 5 0 0 5000550060006500700075007569KBU 14-06Y 500 1000 1500 2000 KBU 22-06 5 0 0 1000 1500 200 0 2500 3000 3500 4000 4500 5000KBU 22-06Y 5001 0 0 0 1 5 0 0 20 0 0 2 5 0 0 3 0 0 0 3 5 0 0 4 0 0 0 4 5 0 0 KBU 23-07 5 0 0 1 0 0 0 1500 2000 2500 3000 3500 4000 KBU 23X-6 0500100015002000 250030003500400045005000KBU 24-0500100015002000 2500300035004000 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 065007 0 0 0 7 5 0 07622KBU 24-06RD 50010001500200025003000 3 50 04 0 0 0 4500KBU 31-0750010001500200025003000 3 50 04 0 0 0 4500KBU 31-07RD 5001000150020002500300035004000450050005 5 0 0 600065007000750080008500KDU 1 5001000150020002500300035004000450050005 5 0 0 600065007000750080008500KDU 1 PB 5001 0 0 0 1 5 0 0 2 0 0 025 003 0 0035 004000 45 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 900095009703KU 11-07X50010001500 2 0 0 0 2 5 0 0 3 0 0 0KU 13-6 5001000150020002500300035004000450050005341KU 14-06RD500100015002000250030003500400045005000550060006500700075008000850090009500100001050011000115001200012500130001350014000145001500015042KU 14-6 500100015002 0 0 0250030003500 400045005000550 0600065007000750080008500900095009905KU 14X-6 5 0 01 0001500200025003000350040004364KU 21-750010001185KU 21-7PB 5 0 0 1 0 0 0 1 5 0 0 2 0 0 0 25003000KU 31-7X 500 1000 1500 2000 2500 3000 KU 43-12 5001000150020002500300035004000450050005500600065006844KU 44-01 wp04 20" 7 5/8" x 9 7/8" 5-1/2" x 6 3/4" 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 5807 KU 42-12 wp06 Azimuths to True North Magnetic North: 14.71° Magnetic Field Strength: 55306.4nT Dip Angle: 73.38° Date: 6/28/2020 Model: BGGM2019 T M Project: Kenai Gas Field Site: KGF 14-6 Pad Well: Plan: KU 42-12 Wellbore: KU 42-12 Plan: KU 42-12 wp06 -333 -167 0 167 333 500 West(-)/East(+) (250 usft/in) -167 0 167 South(-)/North(+) (250 usft/in)1 0 0 0 1 5 0 0 20 00KBU 11-0715002 5 0 0 4 5 0 0 7569KBU 14-06Y 500 KBU 22-06 5 0 0 1000 5001 5 0 0 KBU 23-07 1500 KBU 23X-6 100025003000KBU 24-06 KBU 24-06RD 500150020002500KBU 31-07 KBU 31-07RD 5 5 0 0 KDU 1 500 1 0 0 01 5 0 0 2 0 0 02 500KU 11-07X KU 13-6 5341 KU 14-06RD 50050006 500KU 14X-6 25003000KU 21-7 KU 31-7X KU 43-12 500KU 44-01 wp04 1000 & # ' " # ( )*+ ( ,- . ., -/#- 0 !"#"#$ # %#%&'()**#+ +1 ,* +,-./0 - 1 + ( %#%&'()**#+ 2 0 ( 2 /# ' $ +-' & 3 '+-' 3 4567 #8 - 13 45- 1.-.-8 9* ! $ :2+ :: + % ' "- " 1- 2 01 41 $# /1 #+ ! #+ #+ ;)* -<((= ( (3)* 4 (3)3 *)** *; 4>(4)(?- ?;?>?3)((32 . . " 1- "- 41 2 01 #+ 546. 526 #+ #+ #+$ -"/ #+ #+ *)** *)** ( ((')4 4 *4*)4 ?)**.04/ #+*)?* *; 4>()3((- ?;?>?)''32 ., + 789 %10 7)9 ' + + 1 789 2'1 %! *3 = '= * * )4 4()(' ?? (*)4'33 4 0* -2 +1 ,* - * + 0% '7)*+9 7-(9 526 7-(9 + 789 546. 7-(9 ):+ 0')** *3)4**)***)**')** ; 789 <'-0 789 546. 7-(9 ) % 789 526 7-(9 - + 0 7-(9 * + 0 7-(9 + 11 786-(9 =- 786-(9 )- 786-(9 )*+ ' -( *)***)***)***)***)***)**')***)***)**')**?)** *)***)***)***)***)***)** ?*)***)***)** ?*)**4)** *3)4**)**()**()** *)( ()4* *) *3)4*(')? ?(?) ' (?4) *)***)***)***)**'4)4 ?()3*( (4)44 *3)4*(')?( 4*?)'( *?)44 '*)***)**()**()** * ?)3 43')?( 4?)** *3)4* *)** ( )4 ( ?3 )** '*)***)** )** )** *'3)3? 3*)' ?4)(? *3)4**)** ' )4 *4)(? *)***)***)***)** () ()?? '*4) *3)4**)** ?**)**? 4 ) & # ' " # ( )*+ ( ,- . ., -/#- 0 !"#"#$ # %#%&'()**#+ +1 ,* +,-./0 - 1 + ( %#%&'()**#+ 2 0 ( 2 /# - + 0 7-(9 ; 789 <'-0 789 546. 7-(9 2 01 7-(9 41 7-(9 526 7-(9 -/ * + 0 7-(9 )*+ -( +" >? * ')** *)** ')** *)** *)***)** 4 *4*)4 ( ((')4?)***)** *)** **)** *)** **)** *)** *)***)** 4 *4*)4 ( ((')44)***)** *)** *)** *)** *)** *)** *)***)** 4 *4*)4 ( ((')4(4)***)** *)** @ **)** *)** **)** *)** *)***)** 4 *4*)4 ( ((')44)***)** *)** ?*)** *)** ?*)** *)** *)***)** 4 *4*)4 ( ((')44)***)** *)** +AB6C>C+>C)*+ (**)** )?* 33)33 *)?4 *)( *3)4* 4 *3)'( ( ((4)3 )33 ()** *)? **)** )?* (33)'? ?) )3 *3)4* 4 *4) ( ((()()'?()** ?)'3 ?**)** 4)?* 33) 3 )3 ')* *3)4* 4 *)'* ( ( )) 3 ()** )( **)** *)?* ?3')* 4)4' ?)'? *3)4* 4 *?()'* ( ()**??)*()** ()3' 4**)** ()?* 3?)'? ?)' )? *3)4* 4 *()? ( 3() )'?()** ? )44 '**)** )?* 43 )( ')( (')34 *3)4* 4 * 3)3* ( 4*)3 4*3)(()** 4')? 3**)** 3)?* ''4)? 3?)? ?) ' *3)4* 4 *)*' ( )(''*)? ()** *3)?? ***)** )?* 3'*)'4 ) ' 4 )*( *3)4* 4 33?)4( ( ()*'34)'4 ()** ?)(' **)** ?)?* *4 ) ) 3 )' *3)4* 4 34)3 ( 4')43'3) ()** ')*? **)** ')?* )( *)* )4 *3)4* 4 3?)4 ( (3)' *4')(()** () (**)** ()?* 4)3* ) (3) *3)4* 4 3 )*4 ( *3)4 )3*()** ') **)** ()?* (()4 3)44 )( *3)4* 4 '3')3 ( *3)3 ')4()** ((?)'3 ?**)** (4)?* )? ( )' 3?)?? *3)4* 4 '')*3 ( 333)' ( 3)?()** (3)4 ?(?) ' (')? *) ()4* *)( *3)4* 4 '?)3 ( 3'*)' (?4)()** )* 4+>A>?DC+?C)*+ **)** (')? 3)*? (3)4 )(* *3)4* 4 '()( ( 3) *')*?*)** ?)4 4**)** (')? ?3) ?*)'' ?4)3 *3)4* 4 '*)* ( '3 ) ') *)** ?3)*4 4?*)** (')? *')( 44)3? 4 )( *3)4* 4 4'') ( '?)' ? ?)(*)** ??*) >6D@EF6D@ '**)** (')? 4) ?*?)* '')*4 *3)4* 4 44 )' ( '(3)*3 ?)*)** ?')* 3**)** (')? 4 ?) ??3) (')3? *3)4* 4 4*)?4 ( 4'?)?? )*)** ()4( ***)** (')? '*()' ()(* (3)' *3)4* 4 4*')? ( 4( )* 4 *)'*)** 4*)*4 **)** (')? '' )*( 4)? ('*)4 *3)4* 4 4)4 ( 4')4 433)*(*)** 4')* **)** (')? 3*) ( 4 )?3 ) *3)4* 4 )' ( )3( '44) (*)** '(*)4( (**)** (')? *(')( 44?)4( )3 *3)4* 4 )3 ( ?4)* 3??)(*)** '3()* **)** (')? )( ' 3)'4 4()(4 *3)4* 4 ?'*)33 ( ?4)' *(()(*)** 3??)(3 ?**)** (')? 3)' '')* ?*) *3)4* 4 ?3)*' ( )( )' *)** *4)4 **)** (')? 4()* 3(') ?(?) *3)4* 4 ?4) ( *)4' 3*)* *)** *'*)*? 4**)** (')? (?) 33 )(* ?)* *3)4* 4 '?) ? ( (?4) ? ') *)** )(3 '**)** (')? 3) *) ?3)3 *3)4* 4 ?()(( ( (*()4 ()*)** *)4 3**)** (')? ?*4) **)?3 4)43 *3)4* 4 ) ( ?*)4 )*)** 4)*? ( ***)** (')? ?'?)' ?)4( ?')4 *3)4* 4 ('3)?* ( 3)( ?* )'*)** ( 3)(' ( **)** (')? )* *')'4 '3)? *3)4* 4 (?4)?3 ( ()*3 ?')**)** (3)4 ( **)** (')? 4 ) * ()* 4 *) *3)4* 4 ( ?)4 ( *'3)? ?3) **)** ?)* ( (**)** (')? ' *)* (4)? 4?)(( *3)4* 4 3()4 ( *()* 4(4)**)** ?)(4 ( **)** (')? '3')* (4)(* 4' ) *3)4* 4 )' (* 3' )' '?)**)** ?4')4* ( ?**)** (')? 34)'* ?) '()*3 *3)4* 4 3)3( (* 3 ')3 '3()'**)** )* ( **)** (')? ( *?)33 43)?' '()3' *3)4* 4 3')* (* '4?)* 34)33 *)** 4*()(4 & # ' " # ( )*+ ( ,- . ., -/#- 0 !"#"#$ # %#%&'()**#+ +1 ,* +,-./0 - 1 + ( %#%&'()**#+ 2 0 ( 2 /# - + 0 7-(9 ; 789 <'-0 789 546. 7-(9 2 01 7-(9 41 7-(9 526 7-(9 -/ * + 0 7-(9 )*+ -( +" A>?F * ( 4**)** (')? ( (()3 ?(()4 '4)' *3)4* 4 )* (* ' )'4( *?*)3 *)** 4?)4* ( 4*?)' (')? ( (4)44 ?()3* '4)4 *3)4* 4 ) ( (* '')4(( *?)44 *)** 43)(? +AB6CA>?DC+AA?C)*+ ( '**)** (?)4( ( )'* ?') 4 3*)'( *3)4* 4 (?)( (* 43)3( 3)'*()** ' )3 ( '34)* ( )' ( 3()** (()4? 3()3 *3)4* 4 *4) (* 4 )3( *)**()** ''*)'? AG ( 3**)** ( )4( ( 3?)4 (?)( 3( )4* *3)4* 4 *)( (* 4 )?3( )4 ()** '' ) ***)** 3)4( ( ('*)3 '*)4 3?')(3 *3)4* 4 *43)4' (* 44)*( 34)3()** 3() 3 **)** )4( ( 3)* 4 ) ? 3')'( *3)4* 4 *??)? (* ()(( (')*()** 3')?3 **)** ()4( ( ??3)?* 4?') ' ** )3? *3)4* 4 *(()4( (* ?33)'( 4)?*()** * ) ?3) )3 ( )** 44') ( *)(( *3)4* 4 * )3' (* ?'*)*3( ?()**()** *4)' AG D (**)** *)4( ( ? )* 43)? * )4* *3)4* 4 *)( (* ?4)( ( ?3)*()** * )*? (*')3 *)' ( *)** 43()4 * ()' *3)4* 4 * )'( (* ?)4?( ?44)**()** *?)* AG F ( )4 *)** ( 4?)** 43')? * ?)3 *3)4* 4 **)** (* ?*)**( ?3 )**()** *4*)?4 +B6CA?C+A>C)*+1C- ((*)' 3)'4 ( ')** '**) * )33 *3)4* 4 **')'3 (* ??')(( ?3')** )** *4 )4? AG **)** ')3 ( 4)(* ' *)4 *(') ? *3)4* 4* 334) ? (* ?(') ( ()(* )** *3?) )( ') ( 4?')** ' ()? **)4 *3)4* 4* 33?) 4 (* ?(?) '( 4?)** )** *33)(? AG 3)*' ) ( '()** ')' *? )(* *3)4* 4* 3' )4( (* ?) ?( 4?()** )** ()'( G= ?**)** )3 ( ')' ') 4 *?() *3)4* 4* 3')'4 (* ? )'( 4?')' )** ?)? **)** )3 ( 3(')* '3)4 *)(4 *3)4* 4* 3') * (* '3)'4( '??)* )** ? ) 4**)** )3 *(?) ' ''3)4( *44)3( *3)4* 4* 3?) ? (* 3)'(( 3? ) ' )** 4?)?? '**)** *)3 (() 4 3*4)*( *'4)'* *3)4* 4* 3)*? (* ? )4 *?*) 4 )** 3?) ' )4 *)** ?4)(? 3*)' *'3)3? *3)4* 4* 3()'( (* ')33 *4)(? )** 33)' 4+D?C+>?A>C)*+ 3**)** *)** ()4( 3 ) * *3)? *3)4* 4* 3(4) (* (4)4 ')4(*)** )3( ? ***)** *)** ((*) 3(4) 3 *?)*? *3)4* 4* 3 ') (* )' 4) *)** (*)(* ? **)** *)** ')3 3? )(4 () *3)4* 4* 33)(( (* *4)'3 (?)3 *)** 4) ? 4) *)** ?* )** 3()* *)* *3)4* 4* 3 )4 (* (3)43 3)***)** *)?3 G# ? **)** *)** ? 4)4 34)? ) *3)4* 4* 3*) (* (3 )3' )4 *)** ?)*( ? (**)** *)** ?)? 3' )? (*)' *3)4* 4* 3*)?? (* (4')* ? )?*)** ' )(3 ? ( ?)4 *)** ?)** 3') (()*' *3)4* 4* '33) (* (4) ?')***)** ')' G# ? (3)' *)** 4 )** 334) (3)3 *3)4* 4* '3 )3 (* (() (')***)** 33) * G=4"$ ? **)** *)** 4 )( 334) (3)4 *3)4* 4* '3 ) (* (() )(*)** 33)4 ? ?**)** *)** ' ) * )4 ')*4 *3)4* 4* ''()44 (* (') ( 4(3)*)** (4) ? ??3) 3 *)** '')** * )? ?()4 *3)4* 4* '4')?* (* ((3)(3 43')***)** ( 4) =GA ? **)** *)** 3 )* * 4)43 ?)4 *3)4* 4* '4)'' (* ((()( '(')**)** (()3 & # ' " # ( )*+ ( ,- . ., -/#- 0 !"#"#$ # %#%&'()**#+ +1 ,* +,-./0 - 1 + ( %#%&'()**#+ 2 0 ( 2 /# - + 0 7-(9 ; 789 <'-0 789 546. 7-(9 2 01 7-(9 41 7-(9 526 7-(9 -/ * + 0 7-(9 )*+ -( +" D? * ? (() *)** 3?)** *( )'( ?3)?? *3)4* 4* '4)3* (* ( ')(( '4)***)** (*) 3 =G ? )3 *)** 3'4)** *(4)'' )( *3)4* 4* '')3( (* ( ()(( 3*)***)** () =G ? 4**)** *)** ? *3)?' * )'4 ?) ' *3)4* 4* '?)3' (* (')* 3()?'*)** (?)'? ? 4'4)4 *)** ? *)** *?) 4 )'( *3)4* 4* '?')' (* (*?)(? * ()***)** (4)*3 =G>= ? '**)** *)** ? ')* *?4)3 4()'' *3)4* 4* '?4)*3 (* (*()'? *(?)**)** (3) ? ')3( *)** ? ' )** *4)4? 43)4 *3)4* 4* '?)( (* 3()'*? *33)***)** ('*)3 =G ? '3()( *)** ? *)** *4 )* ')3 *3)4* 4* '')43 (* '3)?? 4)***)** ('?)( =G ? 3**)** *)** ? )? *4()* ' )3 *3)4* 4* '') * (* '')?4? (()?*)** (')?' ? 3?)? *)** ? )** *43)'? ')(4 *3)4* 4* ')3 (* ')'(? 4')***)** (3) =GD ***)** *)** ? (?)* *'') 3)*3 *3)4* 4* '(3)( (* 4()?? ( )* *)** *()3? * )3 *)** ? (44)** *34) 3)?* *3)4* 4* '(()4 (* ) 4? 3)***)** )'4 G=4"$ **)** *)** ? ()?* *() 33)3 *3)4* 4* '(*) (* ?')4? ((*)?**)** )( ') ( *)** ? )** *)' *()' *3)4* 4* ' )( (* ?)?? (4')***)** 3)3 =G **)** *)** ? ?)3' ') 3 *')(* *3)4* 4* ' )?( (* ()' ? ')3'*)** (')4 (()?( *)** ? ??)** ()(? )' *3)4* 4* '')?? (* (')' ? )***)** )?* =GA (**)** *)** ? *) (()(4 )3* *3)4* 4* ' ) (* ')3? ? 4)*)** ?)* **)** *)** ? 4*')3 ') ?)?* *3)4* 4* '*()4? (* ()33? ?)3*)** 4()* 3')? *)** ? '*)** ()( (()3' *3)4* 4* 43)33 (* 33) 3? 4 ()***)** 3*)? =G ?**)** *)** ? '*4) ()? () *3)4* 4* 43)' (* 33)*'? 4 ) *)** 3*)44 ) + 0>C+>D?C)*+>6@EA6@ )12' 06'1 0 )*+ 7-(9 2 01 7-(9 41 7-(9 526 7-(9 546. 7-(9 )1 + 1 789 + +? 789 :>#,*( 4?)** (* ?*)** 4 **)** 43')? * ?)3 *)** *)** @ : 5 #?*)**8 & # ' " # ( )*+ ( ,- . ., -/#- 0 !"#"#$ # %#%&'()**#+ +1 ,* +,-./0 - 1 + ( %#%&'()**#+ 2 0 ( 2 /# * + 0 7-(9 - + 0 7-(9 #1 +' 7@9 +' 7@92' #1 *< *)** *)** * 4?='<734='< *')( 4?*)**4?=' 34=' ?= <7(=<? '*4) ?**)**?= (= - + 0 7-(9 * + 0 7-(9 + + 7892' "0 1 + 789 % ' * + 0 ? ')3( ? ' )** %A4 ( '34)* ( 3()** (A ? (3)' 4 )** A%6 ? 4) ?* )** A ? )3 3'4)** %A )( ( 4?')** (A 3')? ? '*)** !%A ? 4'4)4 ? *)** %A?% (()?( ? ??)** !%A( ? (() 3?)** %A ((*)' ( ')** (A * ? ??3) 3 '')** %A( * )3 ? (44)** !A%6 ? 3?)? ? )** %A' (*')3 ( *)** (A 3 ?3) ( )** (A ' ? '3()( ? *)** %A4 3)*' ( '()** A% ? ( ?)4 ?)** A ') ( ? )** !%A - + 0 7-(9 * + 0 7-(9 546. 7-(9 526 7-(9 " # # '' ?*)** ?*)** *)** *)** 1(B=**> ?*>!1 ?*>/C1 ?(?) ' *) ()4* *)( 61?(?) '>!1 *)>/C1 ( 4*?)' ( (4)44 ?()3* '4)4 1(B=**>(4*?)'>!1 ((4)44>/C1 ( )4 ( 4?)** 43')? * ?)3 1 B=**>( )4>!1 (4?>/C1 ' )4 ?4)(? 3*)' *'3)3? 61' )4>!1 ?4)(?>/C1 ?**)** ? '*4) ()? () / 1@?**>!1 ?'*4) >/C1 !"#$$%&!" &!" &!" '#()*% !"#$"$%&!" "&!" "&!" '# +,)$- .)/*+(01%,#,,23!43 5/#67,#38,94 : 6 :7!:328910) *+% "; ;<2,3 ( *%3#:3 (3 )+3 =%:3 :; %8 5 &3 ((&3-5 & !"#"$ $ >% >%%& *%3#:3 (3 )+3 ($%&!" "&!" '#14"1?4")*< )+/ (0 )/ (05 / (0< )+ ( &3 ((&3-5 & 4 *%3#:3 (3 )+3 +,)$- .)/*+(0()*% !"#$"$%&!" "&!" "&!" '# )+/ (0 ; 1* !"#$'("")*)'("")*)'("")* "+&*, "-& ""&,- "&.- ,.&,"-&/ )'("")*)'("")*)'("")* "+&-" %& ""&,, %0&0, ,-&.%& )'("")*)'("")*)'("")* 0&*- "10%& 0"&%" "10-%&% 0"&."10%&/ )'("+),2)'("+),2)'("+),2 "&0+ "& ".-&0 "+& ,&-0"& )'("+),2)'("+),2)'("+),2 "&- %&% ".-&* %,&++ *-&%-*%&%/ )'("+),2)'("+),2)'("+),2 -*&-, -*%& -&., -,*&%* +"&*+--*%&/ )'(),)'(),)'(), 0&+ "& &"" "+&% ,*&+%+"& )'(),)'(),)'(), 0&+ ".+&". "&"- ".-& "&-.-".+&"./ )'(),)'(),)'(), 0"%&-* ,*%& 0"&% ,&0 %-&*-,,*%&/ )'(),2)'(),2)'(),2 "+&., "-& "0-&, "-& %&++"-&/ )'(),2)'(),2)'(),2 "+"& %& "0,&.0 +.&.+ 0+&+.0%& )'(),2)'(),2)'(),2 ",&- %%& "%%&% %"&", 0&0,%%&/ )'(0)*)'(0)*)'(0)* %*&*- 0.-&%" %+&0 +0&0, ",&-"0.-&%"/ )'(0)*)'(0)*)'(0)* %*&. +%& %+&"* +.&,% "%&%"*+%& )'(0)*)'(0)*)'(0)* ,+&%, %*%& %.&** %*-&"0 "0&+*-%*%&/ )'(03),)'(03),)'(03), %&-- *+&** +,&.0 -%&,. "&--*+&**/ )'(03),)'(03),)'(03), %"&"* 0%& +,&,0 00%&., ""&,.0%& )'(03),)'(03),)'(03), ,&*" %%& %%&+* %%.&** -&,,%%&/ )'(+),)'(+),)'(+), "%&0% *+&"- "&-+ *.&" +"&.+-*+&"-/ )'(+),)'(+),)'(+), "%&+, 0& "&-0 0%& +&*0& )'(+),)'(+),)'(+), "++&.% *%& "0.&+0 **&,- ,&0,*%&/ )'(+),)'(+),)'(+), "%&0% *+&"- "0&% *.&" %&",**+&"-/ )'(+),)'(+),)'(+), "%&+, 0& "0&+ 0%& +*&+,0& )'(+),)'(+),)'(+), "+.&.% *%& "++&,, *%&, -&00-*%&/ )'(0")*)'(0")*)'(0")* "-.&-* -"&%0 "-%&- .,&+, +,&,",-"&%0/ )'(0")*)'(0")*)'(0")* "-.&., 0& "-%&,- 0"+&," ++&0,0& )'(0")*)'(0")*)'(0")* *,&- -%& ,%& -%&,, %&0**-%&/ )'(0")*)'(0")*)'(0")* "-.&-* -"&%0 "-,&* .,&., +.&-,--"&%0/ ) ($%&!" "&!" '#14"1?4")*< )+/ (0 )/ (05 / (0< )+ ( &3 ((&3-5 & 4 *%3#:3 (3 )+3 +,)$- .)/*+(0()*% !"#$"$%&!" "&!" "&!" '# )+/ (0 ; 1*'(0")*)'(0")*)'(0")* "-.&., 0& "-%&.+ 0"%&"" +*&00& )'(0")*)'(0")*)'(0")* *,&- -%& ,%&+, -%0&", ,&"-%&/ )'(")'(")'(" ,+&%- +*"&%. ++&+ +*-&" "&--++*"&%./ )'(")'(")'(" ,-&%+ *%& 0*&" **&" -&%+-*%& )'(")'(")'(" 0-&-* "1"%& *.&-, "1"+&, ,&*""1"%&/ )'(")'("")'("" ,+&%- +*"&%. +0&*- +*-&" "&*".+*"&%./ )'(")'("")'("" ,-&%+ *%& 0,&-% **&" -&+*,*%& )'(")'("")'("" 0-&-* "1"%& *.&%. "1"+&, ,&,*+"1"%&/ )'("")*3)'("")*3)'("")*3 ""*&0 "1*0&*- "*&%" "1+"&- ""&.%-"1*0&*-/ )'("")*3)'("")*3)'("")*3 ""*&0 "1*%& "*&% "1+&.- ""&.%"1*%& )'("")*3)'("")*3)'("")*3 ""-&0* "1"%& "-&. "1.&+ ""&*+,"1"%&/ )'("0),)'("0),)'("0), ".&+% "-& "-.&,+ -&,. ,-&+*%"-&/ )'("0),)'("0),)'("0), ".&,+ "& "-.&0% ".&-+ %-&%.."& )'("0),)'("0),)'("0), *"&-. *%& ,&- *0.&*- -&."*%&/ )'("+),)'("+),)'("+), "%&++ .+.&- ".&,% .0-&++ *&0%.+.&-/ )'("+),)'("+),)'("+), "%&*" .*%& ".&0- .,& *&,+.*%& )'("+),)'("+),)'("+), "%*&.% "1*%& "0+&%" "1%0&, ,&*+"1*%&/ )'("+),)'("+),)'("+), "%&++ .+.&- ".&,% .0-&++ *&0%.+.&-/ )'("+),)'("+),)'("+), "%&*" .*%& ".&0- .,& *&,+.*%& )'("+),)'("+),)'("+), "%*&.% "1*%& "0+&%" "1%0&, ,&*+"1*%&/ )'("+3),)'("+3),4'(-5)'("+3), "0&,* %"&." ".& %,& 0,&00-%"&."/ )'("+3),)'("+3),4'(-5)'("+3), "0&*. *%& "-&-* *.&% 00&-,**%& )'("+3),)'("+3),4'(-5)'("+3), "-.&.. *%& "-&0% *+-&*+ ".&*"*%&/ )'(")*)'(")*)'(")* "%.&-" **+&.+ "+.&+" *-*&+ "%&0,-**+&.+/ )'(")*)'(")*)'(")* "%.&.- -& "+.&0 -""&-* "+&---& )'(")*)'(")*)'(")* "*.&.% "1& ",,&0+ "1"&* "0&%"1&/ )'(")*)'(")*")'(")* .&, *%+&." *-&0 **+&"+ *&0*-*%+&."/ )'(")*)'(")*")'(")* .&%* **%& **&.% *.0&"* *&"*0**%& )'(")*)'(")*")'(")* .*&%. -%& -0&+0 -,0&* ,&----%&/ )'(0")*3)'(0")*3)'(0")*3 "-"&" "-& "*-&0" & ,+&+*"-&/ ) ($%&!" "&!" '#14"1?4")*< )+/ (0 )/ (05 / (0< )+ ( &3 ((&3-5 & 4 *%3#:3 (3 )+3 +,)$- .)/*+(0()*% !"#$"$%&!" "&!" "&!" '# )+/ (0 ; 1*'(0")*3)'(0")*3)'(0")*3 "-"&"* "& "*-&"0 "0&*. %.&,*."& )'(0")*3)'(0")*3)'(0")*3 +,&.. *%& +"& *-&. +"&0,0*%&/ )'(+0)")'(+0)")'(+0)" "*&0 "1*"0&** "+,&. "1%.& *&0%"1*"0&**/ )'(+0)")'(+0)")'(+0)" "*&* "1*%& "+,&-% "1,&+ *&0%"1*%& )'(+0)")'(+0)")'(+0)" "*&0, "1*%& "+,&., "1,%&0+ *&*-"1*%&/ ) '(++)")'(++)")'(++)"+ "-"&+ "& "**&- "& %&*"*"& ) '(++)")'(++)")'(++)"+ "-"&+ %& "*-&*0 %& ,*&.+"%&/ ) '(++)")'(++)")'(++)"+ 0,&. *%& 0&00 ,-,&- +&..**%&/ ) / (0>/ (0 .@$ .>"-& "1*%& '(+)", 0678!"!7 ! 9"1*%& ,1%& '(+)", 0678!"!7 ! 9 : ; <=)& ; >&/ ; ; $ &/ ? $#4 $) 5& 9 >> & ; ;97:;:/; < ; :& 0.001.503.004.50Separation Factor0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650 8100Measured DepthNo-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: KU 42-12 NAD 1927 (NADCON CONUS)Alaska Zone 0465.00+N/-S +E/-W Northing EastingLatittudeLongitude0.000.002362338.47 272070.17 60° 27' 36.933 N151° 15' 45.889 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: KU 42-12, True NorthVertical (TVD) Reference:As-Built RKB @ 83.00usftMeasured Depth Reference:As-Built RKB @ 83.00usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-04-28T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool18.00 1750.00 KU 42-12 wp06 (KU 42-12) 3_MWD+IFR1+MS+Sag1750.00 6500.00 KU 42-12 wp06 (KU 42-12) 3_MWD+IFR1+MS+Sag0.0030.0060.0090.00120.00150.00Centre to Centre Separation (50.00 usft/in)0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200Measured DepthKBU 23-07KBU 23X-6KBU 24-06KBU 24-06RDKU 14X-6GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.00 To 6500.00Project: Kenai Gas FieldSite: KGF 14-6 PadWell: Plan: KU 42-12Wellbore: KU 42-12Plan: KU 42-12 wp06Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name120.00 37.00 120.00 20 20"1608.34 1525.34 1750.00 7-5/8 7 5/8" x 9 7/8"5807.42 5724.42 6500.00 5-1/2 5-1/2" x 6 3/4" WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:KENAI UNIT 42-12Initial Class/TypeDEV / PENDGeoArea820Unit51120On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2200450KENAI, BELUGA/UP TYONEK GAS - 448571NA1 Permit fee attachedYes Surface location and top prod interval in FEE FEE A028142; TD in A028143.2 Lease number appropriateYes3 Unique well name and numberYes Kenai, Beluga/ Upper Tyonek Gas Pool-4485714 Well located in a defined poolYes CO 510A (Corrected), Rule 2: There shall be no restrictions as to well spacing except that no gas pay shall5 Well located proper distance from drilling unit boundaryYes be opened in a well within 1,500’ of an external property line of the Affected Area described above where6 Well located proper distance from other wellsYes the owners and landowners are not the same on both sides of the line. 7 Sufficient acreage available in drilling unitYes As planned, well conforms with spacing requirements.8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes 7 5/8" set at 1750 ft. And will be fully cemented.19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes 5.5 long string will be cemented to the 7 5/8" and swell packer used.21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes BTC supplied23 Casing designs adequate for C, T, B & permafrostYes Rig has steel pits.. All waste to be transported to the KGF disposal wells.24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA Diverter is waived .27 If diverter required, does it meet regulationsYes Max formation press = 8.6 ppg will drill with 9-10 ppg mud28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MASP = 1311 psi Will test BOPE to 3500 psi30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes Separate sundry to perforate the well. CBL and MIT-IA required post rig.32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes Nearby wells did not encounter H2S gas. Measures not required.35 Permit can be issued w/o hydrogen sulfide measuresYes Planned mud weights appear adequate to control the operator's forecast of most likely pore pressures36 Data presented on potential overpressure zonesNA Sterling to Middle Beluga intervals all expected to be under-pressured to severely under-pressured with37 Seismic analysis of shallow gas zonesNA exception of several Middle Beluga sands, which are expected to be approx. normally pressured. Lost38 Seabed condition survey (if off-shore)NA circulation materials will be on site; mitigation discussed in Anticipated Drilling Hazards (p.37-38).39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate5/8/2020ApprGLSDate5/18/2020ApprSFDDate5/8/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateDiverter waived per 20 AAC 25.035 (h)(2) glsJMP5/19/2020dts 5/19/2020JLC 5/19/2020