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Home My WebLink About217-028Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 T41315KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,265' N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker Swell Packer & N/A 1,280 (MD) / 1,203 (TVD) & N/A 8,173' 5,555' 4,721' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINU Kalotsa 03CO 701C Same 8,160'4-1/2" ~1209 psi 9,252' See schematic Length January 6, 2026 N/A 9,252' Perforation Depth MD (ft): See Attached Schematic 2,980psi 6,890psi 120'120' 1,418' Size 120' 1,418' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,316' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0359242 / ADL0384372 / FEE-CIRI 217-028 50-133-20661-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.12.30 13:40:32 - 09'00' Noel Nocas (4361) 325-778 By Grace Christianson at 2:00 pm, Dec 30, 2025 DSR-1/2/26 10-404 Obtain AOGCC approval before setting plugs. SFD 12/31/2025 Perforate BJM 1/6/26 01/06/26 Well Prognosis Well Name: Kalotsa 3 API Number: 50-133-20661-00-00 Current Status: Producing Gas Well Permit to Drill Number: 217-028 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 1565 psi @ 3556 TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 1209 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .74 psi/ft using 14.2 ppg EMW LOT at the 7-5/8 surface casing shoe Shallowest Allowable Perf TVD: MPSP/(.74-0.1) = 1209 psi / .64 = 1889 TVD Top of Applicable Gas Pool: 1555 MD/1428 TVD (Beluga-Tyonek) Well Status: Online Gas producer 587 mscfd, 110 bwpd, 49 psi FTP Recent SITP: 414 psi max SITP when bailing fill in May 2025 Brief Well Summary Kalotsa 3 was drilled and completed in July 2017, targeting the deep Tyonek sands. Since completion, the well has undergone several re-completions and perforation campaigns to improve production performance. In 2019, perforations were added in the T4 through T12 intervals, which temporarily boosted the gas rate to approximately 1 MMscfd but these intervals declined quickly. In July 2020, additional perforations were introduced in T2, T5, and T6, resulting in a rate increase of about 2 MMscfd. By September 2021, the rate had fallen below 1 MMscfd, prompting further perforations in additional Tyonek sands and the Bel 135 upper and lower intervals. The BEL 135L interval produced water and was subsequently patched, restoring the rate to around 2 MMscfd. Production declined again by May 2022, dropping below 1 MMscfd. At that time, multiple Beluga sands were perforated, which initially improved the rate to approximately 2.8 MMscfd. In February 2025, perforations were added to the upper Tyonek sands, but this intervention did not result in any increase in gas rate. Since then, water production has continued to rise, and recent slickline operations have encountered fill in the wellbore. The objective of this sundry is to add additional perforations to the Beluga sands to increase the rate. Notes Regarding Wellbore Condition Inclination o Max inclination = 36.98° at 4049 MD o Max DLS: 5.53° @ 414 MD Min ID o 3.375 (XSpan Permanent Patch at 4227-4245 MD) Recent Tags o 8/5/25 SL tagged at 4991 w/ 2.5 x 6 DD DD bailer o 7/7/25 SL tagged at 5269 w/ 2.5 GR o 5/23/25: SL bailed fill from 5080 5320 KB w/ 2.25 - 3 x 5 DD bailer o 2/14/25: SL bailed fill from 4732 4816 with a 3 DD bailer. Fell through bridge and tagged at 5504 KB Shallowest Allowable perf should be based on deepest open perf unless evidence is provided to demonstrate that existing perfs are depleted. See evidence in attached email from Scott Warner 1/5/26. -bjm Well Prognosis Pre-Sundry Steps: 1. RU slickline 2. PT lubricator to 250 psi low/ 2,500 psi high 3. D&T to TD w/ large OD drift to find updated tag and ensure wellbore is clean of any sand bridges o Note if fluid level is seen o Last SL tag was 4991 KB w/ 3 x 6 DD bailer in August 2025 4. RDMO slickline Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate BEL 59 BEL 134 sands from bottom up: Zone Top MD Btm MD Top TVD Btm TVD Footage BEL 59 2,737' 2,745' 2,401' 2,407' 8' BEL 59 2,751' 2,761' 2,412' 2,421' 10' BEL 60 2,809' 2,819' 2,460' 2,468' 10' BEL 60 2,819' 2,829' 2,468' 2,477' 10' BEL 65 2,848' 2,851' 2,493' 2,495' 3' BEL 65 2,851' 2,861' 2,495' 2,503' 10' BEL 65 2,861' 2,885' 2,503' 2,523' 24' BEL 70 2,888' 2,891' 2,526' 2,528' 3' BEL 70 2,891' 2,901' 2,528' 2,536' 10' BEL 70 2,901' 2,903' 2,536' 2,538' 2' BEL 70 2,908' 2,914' 2,542' 2,547' 6' BEL 72 2,933' 2,937' 2,563' 2,566' 4' BEL 72 2,944' 2,948' 2,572' 2,575' 4' BEL 73 2,954' 2,958' 2,580' 2,583' 4' BEL 73 2,960' 2,966' 2,585' 2,590' 6' BEL 73 2,970' 2,974' 2,593' 2,596' 4' BEL 74 2,978' 2,982' 2,600' 2,603' 4' BEL 74 3,000' 3,005' 2,618' 2,622' 5' BEL 74 3,017' 3,021' 2,632' 2,635' 4' BEL 74 3,026' 3,031' 2,639' 2,643' 5' BEL 75 3,038' 3,043' 2,649' 2,653' 5' BEL 75 3,056' 3,061' 2,664' 2,668' 5' BEL 80 3,087' 3,096' 2,689' 2,696' 9' BEL 81 3,109' 3,113' 2,707' 2,710' 4' BEL 81 3,114' 3,120' 2,711' 2,716' 6' BEL 82 3,123' 3,133' 2,718' 2,726' 10' BEL 82 3,152' 3,156' 2,742' 2,745' 4' BEL 83 3,166' 3,170' 2,753' 2,756' 4' BEL 83 3,177' 3,181' 2,762' 2,765' 4' BEL 88 3,191' 3,199' 2,773' 2,780' 8' Well Prognosis BEL 90 3,223' 3,227' 2,800' 2,803' 4' BEL 90 3,231' 3,235' 2,806' 2,809' 4' BEL 90 3,236' 3,240' 2,810' 2,814' 4' BEL 90 3,244' 3,253' 2,817' 2,824' 9' BEL 90 3,273' 3,281' 2,841' 2,847' 8' BEL 91 3,287' 3,293' 2,852' 2,857' 6' BEL 91 3,303' 3,308' 2,866' 2,870' 5' BEL 91 3,321' 3,330' 2,880' 2,888' 9' BEL 91 3,333' 3,339' 2,890' 2,895' 6' BEL 92 3,348' 3,352' 2,903' 2,906' 4' BEL 92 3,372' 3,377' 2,923' 2,927' 5' BEL 92 3,384' 3,389' 2,932' 2,937' 5' BEL 92 3,399' 3,403' 2,945' 2,948' 4' BEL 92 3,412' 3,416' 2,955' 2,959' 4' BEL 92 3,419' 3,425' 2,961' 2,966' 6' BEL 92 3,428' 3,436' 2,969' 2,975' 8' BEL 93 3,460' 3,466' 2,995' 3,000' 6' BEL 93 3,471' 3,476' 3,004' 3,008' 5' BEL 93 3,481' 3,485' 3,012' 3,016' 4' BEL 94 3,498' 3,502' 3,026' 3,030' 4' BEL 95 3,528' 3,534' 3,051' 3,056' 6' BEL 95 3,538' 3,544' 3,059' 3,064' 6' BEL 95 3,548' 3,553' 3,067' 3,071' 5' BEL 95 3,560' 3,564' 3,077' 3,081' 4' BEL 95 3,566' 3,570' 3,082' 3,085' 4' BEL 95 3,572' 3,576' 3,087' 3,090' 4' BEL 95 3,581' 3,586' 3,094' 3,099' 5' BEL 97 3,620' 3,626' 3,127' 3,131' 6' BEL 98 3,648' 3,652' 3,150' 3,153' 4' BEL 98 3,656' 3,670' 3,156' 3,168' 14' BEL 98 3,676' 3,680' 3,173' 3,176' 4' BEL 99 3,698' 3,704' 3,191' 3,196' 6' BEL 99A 3,719' 3,725' 3,208' 3,213' 6' BEL 99A 3,729' 3,739' 3,217' 3,225' 10' BEL 99B 3,751' 3,760' 3,235' 3,242' 9' BEL 100 3,792' 3,796' 3,269' 3,272' 4' BEL 100 3,826' 3,830' 3,297' 3,301' 4' BEL 110 3,864' 3,874' 3,329' 3,337' 10' BEL 115 3,915' 3,919' 3,370' 3,374' 4' BEL 134 4,115' 4,120' 3,531' 3,535' 5' BEL 134 4,126' 4,130' 3,540' 3,543' 4' BEL 134 4,146' 4,150' 3,556' 3,559' 4' Well Prognosis a. Proposed perfs are 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. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Patch will most likely be used to avoid shutting off current production g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure N2 Operations Plugs are not approved as part of this sundry. Obtain AOGCC approval before setting plugs. -bjm Updated by SRW 12-16-25 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 PBTD = 5,555 / PBTVD = 4,721 TD = 9,265 / TVD = 8,173 RKB to GL = 19.1 1 16 7-5/8 4-1/2 No.Depth MD Depth TVD ID Item 1 1,2801,2033.958Swell Packer 2 4,2273,6213.375X-Span - Permanent Patch 4,227-4,245 09/17/21 3 5,5554,721CIBP 03/16/19 4 6,8815,8393.375Permanent Patch 6,881-6,903 11/06/17 5 8,7607,670CIBP w/ 10 of cement 10/21/17 6 8,9507,859CIBP w/ 26 cement 10/12/17 7 9,0127,921CIBP w/ 5 of cement 9/10/17 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 X-56 Weld 15.01Surf 120' 7-5/8"Surf Csg 29.7 L-80 BTC 6.875Surf 1,418 4-1/2"Prod Csg 12.6 L-80 TXP 3.958Surf 9,252 OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8 hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2 6-3/4 hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430 MD. ToC at 1,180 MD RA @ 3,987 RA @ 5,438 RA @ 6,474 RA @ 7,470 7 T146 T147 T43 5 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL 105 3,813'3,820'3,286'3,292'7'5/11/2022 Open BEL 120U 3,974'3,992'3,418'3,433'18'5/11/2022 Open BEL 120M 3,995' 4,022' 3,435' 3,457' 27' 5/11/2022 Open BEL 120L 4,024' 4,030' 3,458' 3,463' 6' 5/11/2022 Open BEL 131 4,060' 4,067' 3,487' 3,493' 7' 5/12/2022 Open BEL 132 4,077' 4,081' 3,501' 3,504' 4' 5/12/2022 Open BEL 133 4,094' 4,099' 3,515' 3,519' 5' 5/12/2022 Open BEL_135U 4,209 4,214 3,607 3,611 509/15//21 Open BEL_135L 4,231 4,241 3,625 3,633 109/17/21 Isolated T2 4,451' 4,465' 3,802' 3,814' 14' 2/21/25 Open T2 4,501 4,517 3,843 3,85616 07/30/20 Open TY3 4,517' 4,537' 3,856' 3,872' 20' 2/21/25 Open TY3 4,561' 4,567' 3,891' 3,896' 6' 2/21/25 Open T4 4,632 4,643 3,950 3,95911 08/22/19 Open T5 4,654 4,661 3,968 3,9747 07/30/20 Open T-5L 4,681 4,686 3,991 3,995 59/15/21 Open T5A 4,714' 4,720' 4,018' 4,023' 6' 2/21/25 Open T5A 4,731' 4,737' 4,032' 4,037' 6' 2/21/25 Open T5B 4,793 4,799 4,085 4,0906 07/30/20 Open T6 4,868' 4,888' 4,148' 4,165' 20' 2/21/25 Open T6 4,909' 4,915' 4,183' 4,188' 6' 2/21/25 Open T6A 4,984 4,994 4,246 4,25410 07/30/20 Open T7 5,005' 5,011' 4,264' 4,269' 6' 2/21/25 Open T8 5,058 5,078 4,308 4,32520 08/22/19 Open T8 5,079 5,102 4,326 4,345 239/14/21 Open T8 5,102' 5,108' 4,345' 4,350' 6' 2/21/25 Open (continued on following page) 4 T142 6 3 2 Bel 135 T2 Thru T18 Bel 105 Bel 120 Bel 133 Bel 132 Bel 131 Updated by SRW 12-16-25 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 PERFORATION DETAIL (continued from previous page) Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T-9A 5,184 5,190 4,415 4,419 6 9/14/21 Open T10 5,259 5,269 4,478 4,486 10 08/22/19 Open 5,276 5,286 4,492 4,501 10 08/22/19 Open T11 5,354 5,370 4,557 4,570 16 8/14/19 Open T-11A 5,386 5,404 4,583 4,597 14 9/14/21 Open T12 5,520 5,545 4,692 4,713 30 03/15/19 Open T12 5,562 5,582 4,727 4,743 20 10/13/18 Isolated T17A 6,249 6,259 5,298 5,307 10 11/06/17 Isolated 6,259 6,265 5,307 5,312 6 12/14/17 Isolated 6,270 6,285 5,316 5,328 15 12/14/17 Isolated T18 6,418 6,433 5,440 5,452 15 02/07/18 Isolated T43 6,887 6,899 5,844 5,855 12 10/21/17 Isolated T142 8,767 8,777 7,677 7,687 10 10/13/17 Isolated T146 8,975 8,995 7,884 7,904 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated Updated by SRW 12-16-25 PROPOSED SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 PBTD = 5,555 / PBTVD = 4,721 TD = 9,265 / TVD = 8,173 RKB to GL = 19.1 1 16 7-5/8 4-1/2 No.Depth MD Depth TVD ID Item 1 1,2801,2033.958Swell Packer 2 4,2273,6213.375X-Span - Permanent Patch 4,227-4,245 09/17/21 3 5,5554,721CIBP 03/16/19 4 6,8815,8393.375Permanent Patch 6,881-6,903 11/06/17 5 8,7607,670CIBP w/ 10 of cement 10/21/17 6 8,9507,859CIBP w/ 26 cement 10/12/17 7 9,0127,921CIBP w/ 5 of cement 9/10/17 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 X-56 Weld 15.01Surf 120' 7-5/8"Surf Csg 29.7 L-80 BTC 6.875Surf 1,418 4-1/2"Prod Csg 12.6 L-80 TXP 3.958Surf 9,252 OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8 hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2 6-3/4 hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430 MD. ToC at 1,180 MD RA @ 3,987 RA @ 5,438 RA @ 6,474 RA @ 7,470 7 T146 T147 T43 5 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL 59 2,737'2,745'2,401'2,407'8'TBD Proposed BEL 59 2,751'2,761'2,412'2,421'10'TBD Proposed BEL 60 2,809'2,819'2,460'2,468'10'TBD Proposed BEL 60 2,819'2,829'2,468'2,477'10'TBD Proposed BEL 65 2,848'2,851'2,493'2,495'3'TBD Proposed BEL 65 2,851'2,861'2,495'2,503'10'TBD Proposed BEL 65 2,861'2,885'2,503'2,523'24'TBD Proposed BEL 70 2,888'2,891'2,526'2,528'3'TBD Proposed BEL 70 2,891'2,901'2,528'2,536'10'TBD Proposed BEL 70 2,901' 2,903' 2,536' 2,538' 2' TBD Proposed BEL 70 2,908' 2,914' 2,542' 2,547' 6' TBD Proposed BEL 72 2,933' 2,937' 2,563' 2,566' 4' TBD Proposed BEL 72 2,944' 2,948' 2,572' 2,575' 4' TBD Proposed BEL 73 2,954' 2,958' 2,580' 2,583' 4' TBD Proposed BEL 73 2,960' 2,966' 2,585' 2,590' 6' TBD Proposed BEL 73 2,970' 2,974' 2,593' 2,596' 4' TBD Proposed BEL 74 2,978' 2,982' 2,600' 2,603' 4' TBD Proposed BEL 74 3,000' 3,005' 2,618' 2,622' 5' TBD Proposed BEL 74 3,017' 3,021' 2,632' 2,635' 4' TBD Proposed BEL 74 3,026' 3,031' 2,639' 2,643' 5' TBD Proposed BEL 75 3,038' 3,043' 2,649' 2,653' 5' TBD Proposed BEL 75 3,056' 3,061' 2,664' 2,668' 5' TBD Proposed BEL 80 3,087' 3,096' 2,689' 2,696' 9' TBD Proposed BEL 81 3,109' 3,113' 2,707' 2,710' 4' TBD Proposed BEL 81 3,114' 3,120' 2,711' 2,716' 6' TBD Proposed BEL 82 3,123' 3,133' 2,718' 2,726' 10' TBD Proposed BEL 82 3,152' 3,156' 2,742' 2,745' 4' TBD Proposed BEL 83 3,166' 3,170' 2,753' 2,756' 4' TBD Proposed BEL 83 3,177' 3,181' 2,762' 2,765' 4' TBD Proposed BEL 88 3,191' 3,199' 2,773' 2,780' 8' TBD Proposed BEL 90 3,223' 3,227' 2,800' 2,803' 4' TBD Proposed BEL 90 3,231' 3,235' 2,806' 2,809' 4' TBD Proposed BEL 90 3,236' 3,240' 2,810' 2,814' 4' TBD Proposed (continued on following page) 4 T142 6 3 2 Bel 135 T2 Thru T18 Bel 105 Bel 120 Bel 133 Bel 132 Bel 131 Bel 59-100 Bel 110/115 Bel 134 Updated by SRW 12-16-25 PROPOSED SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 PERFORATION DETAIL (continued from previous page) Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL 90 3,244' 3,253' 2,817' 2,824' 9' TBD Proposed BEL 90 3,273' 3,281' 2,841' 2,847' 8' TBD Proposed BEL 91 3,287' 3,293' 2,852' 2,857' 6' TBD Proposed BEL 91 3,303' 3,308' 2,866' 2,870' 5' TBD Proposed BEL 91 3,321' 3,330' 2,880' 2,888' 9' TBD Proposed BEL 91 3,333' 3,339' 2,890' 2,895' 6' TBD Proposed BEL 92 3,348' 3,352' 2,903' 2,906' 4' TBD Proposed BEL 92 3,372' 3,377' 2,923' 2,927' 5' TBD Proposed BEL 92 3,384' 3,389' 2,932' 2,937' 5' TBD Proposed BEL 92 3,399' 3,403' 2,945' 2,948' 4' TBD Proposed BEL 92 3,412' 3,416' 2,955' 2,959' 4' TBD Proposed BEL 92 3,419' 3,425' 2,961' 2,966' 6' TBD Proposed BEL 92 3,428' 3,436' 2,969' 2,975' 8' TBD Proposed BEL 93 3,460' 3,466' 2,995' 3,000' 6' TBD Proposed BEL 93 3,471' 3,476' 3,004' 3,008' 5' TBD Proposed BEL 93 3,481' 3,485' 3,012' 3,016' 4' TBD Proposed BEL 94 3,498' 3,502' 3,026' 3,030' 4' TBD Proposed BEL 95 3,528' 3,534' 3,051' 3,056' 6' TBD Proposed BEL 95 3,538' 3,544' 3,059' 3,064' 6' TBD Proposed BEL 95 3,548' 3,553' 3,067' 3,071' 5' TBD Proposed BEL 95 3,560' 3,564' 3,077' 3,081' 4' TBD Proposed BEL 95 3,566' 3,570' 3,082' 3,085' 4' TBD Proposed BEL 95 3,572' 3,576' 3,087' 3,090' 4' TBD Proposed BEL 95 3,581' 3,586' 3,094' 3,099' 5' TBD Proposed BEL 97 3,620' 3,626' 3,127' 3,131' 6' TBD Proposed BEL 98 3,648' 3,652' 3,150' 3,153' 4' TBD Proposed BEL 98 3,656' 3,670' 3,156' 3,168' 14' TBD Proposed BEL 98 3,676' 3,680' 3,173' 3,176' 4' TBD Proposed BEL 99 3,698' 3,704' 3,191' 3,196' 6' TBD Proposed BEL 99A 3,719' 3,725' 3,208' 3,213' 6' TBD Proposed BEL 99A 3,729' 3,739' 3,217' 3,225' 10' TBD Proposed BEL 99B 3,751' 3,760' 3,235' 3,242' 9' TBD Proposed BEL 100 3,792' 3,796' 3,269' 3,272' 4' TBD Proposed BEL 100 3,826' 3,830' 3,297' 3,301' 4' TBD Proposed BEL 105 3,813' 3,820' 3,286' 3,292' 7' 5/11/2022 Open BEL 110 3,864' 3,874' 3,329' 3,337' 10' TBD Proposed BEL 115 3,915' 3,919' 3,370' 3,374' 4' TBD Proposed BEL 120U 3,974' 3,992' 3,418' 3,433' 18' 5/11/2022 Open BEL 120M 3,995' 4,022' 3,435' 3,457' 27' 5/11/2022 Open BEL 120L 4,024' 4,030' 3,458' 3,463' 6' 5/11/2022 Open BEL 131 4,060' 4,067' 3,487' 3,493' 7' 5/12/2022 Open BEL 132 4,077' 4,081' 3,501' 3,504' 4' 5/12/2022 Open BEL 133 4,094' 4,099' 3,515' 3,519' 5' 5/12/2022 Open BEL 134 4,115' 4,120' 3,531' 3,535' 5' TBD Proposed BEL 134 4,126' 4,130' 3,540' 3,543' 4' TBD Proposed BEL 134 4,146' 4,150' 3,556' 3,559' 4' TBD Proposed BEL_135U 4,209 4,214 3,607 3,611 5 09/15//21 Open BEL_135L 4,231 4,241 3,625 3,633 10 9/17/21 Isolated T2 4,451' 4,465' 3,802' 3,814' 14' 2/21/25 Open T2 4,501 4,517 3,843 3,856 16 07/30/20 Open TY3 4,517' 4,537' 3,856' 3,872' 20' 2/21/25 Open TY3 4,561' 4,567' 3,891' 3,896' 6' 2/21/25 Open T4 4,632 4,643 3,950 3,959 11 08/22/19 Open T5 4,654 4,661 3,968 3,974 7 07/30/20 Open T-5L 4,681 4,686 3,991 3,995 5 9/15/21 Open T5A 4,714' 4,720' 4,018' 4,023' 6' 2/21/25 Open T5A 4,731' 4,737' 4,032' 4,037' 6' 2/21/25 Open T5B 4,793 4,799 4,085 4,090 6 07/30/20 Open T6 4,868' 4,888' 4,148' 4,165' 20' 2/21/25 Open T6 4,909' 4,915' 4,183' 4,188' 6' 2/21/25 Open T6A 4,984 4,994 4,246 4,254 10 07/30/20 Open T7 5,005' 5,011' 4,264' 4,269' 6' 2/21/25 Open Updated by SRW 12-16-25 PROPOSED SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 T8 5,058 5,078 4,308 4,325 20 08/22/19 Open T8 5,079 5,102 4,326 4,345 23 9/14/21 Open T8 5,102' 5,108' 4,345' 4,350' 6' 2/21/25 Open T-9A 5,184 5,190 4,415 4,419 6 9/14/21 Open T10 5,259 5,269 4,478 4,486 10 08/22/19 Open 5,276 5,286 4,492 4,501 10 08/22/19 Open T11 5,354 5,370 4,557 4,570 16 8/14/19 Open T-11A 5,386 5,404 4,583 4,597 14 9/14/21 Open T12 5,520 5,545 4,692 4,713 30 03/15/19 Open T12 5,562 5,582 4,727 4,743 20 10/13/18 Isolated T17A 6,249 6,259 5,298 5,307 10 11/06/17 Isolated 6,259 6,265 5,307 5,312 6 12/14/17 Isolated 6,270 6,285 5,316 5,328 15 12/14/17 Isolated T18 6,418 6,433 5,440 5,452 15 02/07/18 Isolated T43 6,887 6,899 5,844 5,855 12 10/21/17 Isolated T142 8,767 8,777 7,677 7,687 10 10/13/17 Isolated T146 8,975 8,995 7,884 7,904 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated 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 McLellan, Bryan J (OGC) From:Scott Warner <scott.warner@hilcorp.com> Sent:Monday, January 5, 2026 3:31 PM To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] Kalotsa 3 (PTD 217-028) perf sundry application Bryan, Maximum SITP we have seen is 414 psi. A PPROF was ran in March 2025 showing a maximum gradient of 0.1 psi/. Using this data the current maximum BHP at the T-12 perfs/4692 TVD is ~ 883 psi. Thanks, Scott Warner Kenai Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 To help protect your priv acy, Microsoft Office prevented automatic download of this picture from the Internet. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, January 5, 2026 11:50 AM To: Scott Warner <scott.warner@hilcorp.com> Subject: [EXTERNAL] Kalotsa 3 (PTD 217-028) perf sundry application Scott, When I calculate the shallowest allowable perf, I use the original reservoir pressure at the deepest open perf as a basis, unless the operator provides evidence the deeper zones are depleted. I calculate 2500 TVD as the shallowest in this well, which means the top ~100 of requested addperfs would not be allowed. Can Hilcorp provide evidence of to what extent the existing perfs are depleted? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. 2 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: 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:Tabitha Timothy To:Brooks, James S (OGC) Subject:Kalotsa 3 & 4 Question Date:Thursday, December 18, 2025 11:45:02 AM Attachments:image001.pngimage002.png Good Afternoon, It was brought to my attention earlier this year that two wells had API numbers swapped between the two of them in our previous accounting system. It was found when we changed systems, but unfortunately the production was reported to AOGCC incorrectly up until 05/2025. These wells both came online in 2017. The API is correct here in Data Miner but in our system was flipped and therefore in the Data Miner Production tab the 07/2017-04/2025 reports that were loaded based on our EDIs have production volumes flipped. I am trying to determine the best way to correct this. Is there a way on your end that you can switch the production reports for these two wells? Or will I need to submit a new Field 562 Report with all the wells in Ninilchik for this 8 year period. Thank you, Tabitha Timothy Production Accounting Lead Hilcorp – Alaska Direct: 713.289.2889 Cell: 832.702.0982 2025 Customer Service Goal: In a world full of 2’s…BE A 3! 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 immediatelynotify 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. 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: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40292KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,265 feet See schematic feet true vertical 8,173 feet N/A feet Effective Depth measured 5,555 feet 1,280 feet true vertical 4,721 feet 1,203 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A 1,280 (MD) Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr 1,203 (TVD) SSSV: NA 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: Scott Warner, Operations Engineer 325-016 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 967 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 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 01022 0 430 50 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-028 50-133-20661-00-00 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: ADL0359242 / ADL0384372 / Fee CIRI Ninilchik Field / Beluga-Tyonek Gas NINU Kalotsa 3 Plugs Junk measured Length Production Liner 9,252' Casing Structural 8,160'9,252' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,418' 7,500psi 2,980psi 6,890psi 8,430psi 1,418'1,316' 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 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517) Date: 2025.04.08 13:20:20 - 08'00' Chad Helgeson (1517) By Grace Christianson at 3:58 pm, Apr 08, 2025 DSR-4/11/25BJM 6/11/25 Page 1/1 Well Name: NINU Kalotsa 03 Report Printed: 4/4/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20661-00-00 Field Name:Ninilchik State/Province:Alaska Permit to Drill (PTD) #:217-028 Sundry #:325-016 Rig Name/No: Jobs Actual Start Date:2/6/2025 End Date: Report Number 1 Report Start Date 2/14/2025 Report End Date 2/14/2025 Last 24hr Summary D&T w/ 3.75'' g-ring to 4115'kb tag patch Bail fill from 4735' to 4742'kb full bailers dry sand w/ soap sticks PTW/PJSM. FTP 40 psi. RU Pollard Slickline. PT lubricator 250 psi low / 2500 psi high - good test. RIH w/ 3.75" GR and tag casing patch @ 4,115' RKB. RIH w/ 2 7/8" x 20' dummy gun and tag @ 4,738' RKB. RIH w/ 2 1/2" bailer and bail fill from 4,735' to 4,742' in 3 runs. Recovering coarse sand w/ soap chunks. Secure well and SDFN. Report Number 2 Report Start Date 2/17/2025 Report End Date 2/17/2025 Last 24hr Summary PTW/PJSM. SITP 235 psi. RU Pollard Slickline. PT lubricator 250 psi low / 2500 psi high - good test. Bail fill from 4,732' to 4,789' RKB in 9 runs using 2", 2 1/2", and 3" bailers. Recovering full bailers of dry sand and soap sticks. Secure well, SDFN. Report Number 3 Report Start Date 2/18/2025 Report End Date 2/18/2025 Last 24hr Summary PTW/PJSM. SITP 255 psi. RU Pollard Slickline. Bail fill from 4,791' to 4,812' RKB in 8 runs using 2", 2 1/4", 2 1/2", and 3" bailers. Recovering full bailers of dry sand and soap sticks. RIH w/ 3.25" scratcher to 4,800'. Secure well, SDFN. Report Number 4 Report Start Date 2/19/2025 Report End Date 2/19/2025 Last 24hr Summary Bail fill from 4796' to 5504' broke thru 2 bridges @ 4814' & 4990'kb PTW/PJSM. SITP 270 psi. RU Pollard Slickline. Bail fill from 4,796' to 4,816' RKB in 7 runs and fell through bridge to tag @ 5,504' RKB with 3" bailer. Secure well, SDFN. Report Number 5 Report Start Date 2/21/2025 Report End Date 2/21/2025 Last 24hr Summary PTW/PJSM. 275 psi SITP. MIRU YJ E-line. PT lubricator to 2500 psi - good test. RIH w/ GPT and find fluid level ~ 5,356'. RIH w/ 6'x6'x6' 2 3/8" 5 SPF 60 DEG guns on switch and perf TY_8 (5,102’ – 5,108’), TY_7 (5,005’ – 5,011’), and TY_6 Lower (4,909’ – 4,915’). RIH w/ 20' x 2 3/4" 6 SPF 60 DEG guns and perf TY_6 Upper (4,868’ – 4,888’). RIH w/ 6'x6'x6' 2 3/8" 5 SPF 60 DEG guns on switch and perf TY_5A Lower (4,731’ – 4,737’), TY_5A Upper (4,714’ – 4,720’), and TY_3 Lower (4,561’ – 4,567’). RIH w/ 20' x 2 3/4" 6 SPF 60 DEG guns and perf TY_3 Upper (4,517’ – 4,537’). RIH w/ 14' x 2 3/4" 6 SPF 60 DEG guns and perf TY_2 (4,451’ – 4,465’). Secure well, RD YJ Eline, flow well. Report Number 6 Report Start Date 2/22/2025 Report End Date 2/22/2025 Last 24hr Summary PTW/PJSM. Well flowing 1.4MM @ 50 psi. RU YJ E-line. RIH w/ 2.75" GPT and log down pass @ 180 FPM to tag 5,480'. Log up pass @ 180 FPM to above perfs. Log down pass @ 90 FPM from 4,100' to 5,100'. Did not see static fluid level. Secure well, RDMO YJ E-line. Report Number 7 Report Start Date 3/3/2025 Report End Date 3/4/2025 Last 24hr Summary PTW/PJSM. MIRU AK E-line. PT PCE to 250 psi low / 3000 psi high. Drifted w/3.12' gauge ring to 5445', hard tag. Ran Pprof BHA w/ILS and tagged @ 5105' in TY_8 5102'-5108'. Make dynamic down/up passes from 4300' - 5030' @ 40 fpm / 80 fpm / 120 fpm. Make 5 min stop counts above TY_7, TY_6, TY_5A, TY_3, and TY_2. Send logs to GSA analyst. RDMO AK Eline. Report Number 8 Report Start Date 3/12/2025 Report End Date 3/26/2025 Last 24hr Summary MIRU capillary string truck. Load 3/8" spool. Stab pipe through injector head and pack off assembly. Make up 1" OD SS footvalve set 2200 psi. Stab on well. PT pack off assembly 250/3500 psi. RIH with cap string to 3780'. hang off at depth. Hang off in tension with 1300 lbs of up weight. Presure up dynamic pack off to 3500 psil. Lock in static pack offs. PIck injrector head and land offf back unit. Continue to rig down cap string truck. perf TY_6g Upper (4,868’ – 4,888’). pg perf TY_8 (5,102’ – 5,108’), TY_7 (5,005’ – 5,011’), and TY_6 Lower (4,909’ – 4,915’p perf TY_2 (4,451’ – 4,465’). )g perf TY_5A Lower (4,731’ – 4,737’), TY_5A Upper (4,714’ – 4,720’), and TY_3 p _(, , ), _ Lower (4,561’ – 4,567’) pp ( , , ) (,perf TY_3 Upper (4,517’ – 4,537’). p _(, pppgj RIH with cap string to 3780'. hang off at depth Updated by DMA 04-04-25 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ 1 16” 7-5/8” 4-1/2” No.Depth MD Depth TVD ID Item 1 1,280’1,203’3.958”Swell Packer 2 4,227’3,621’3.375”X-Span - Permanent Patch 4,227’-4,245’ 09/17/21 3 5,555’4,721’CIBP 03/16/19 4 6,881’5,839’3.375”Permanent Patch 6,881’-6,903’ 11/06/17 5 8,760’7,670’CIBP w/ 10’ of cement 10/21/17 6 8,950’7,859’CIBP w/ 26’ cement 10/12/17 7 9,012’7,921’CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875”Surf 1,418’ 4-1/2"Prod Csg 12.6 L-80 TXP 3.958”Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430’ MD. ToC at 1,180’ MD RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 7 T146 T147 T43 5 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft Date Status BEL 105 3,813'3,820'3,286'3,292'7'5/11/2022 Open BEL 120U 3,974'3,992'3,418'3,433'18'5/11/2022 Open BEL 120M 3,995'4,022'3,435'3,457'27'5/11/2022 Open BEL 120L 4,024'4,030'3,458'3,463'6'5/11/2022 Open BEL 131 4,060'4,067'3,487'3,493'7'5/12/2022 Open BEL 132 4,077'4,081'3,501'3,504'4'5/12/2022 Open BEL 133 4,094'4,099'3,515'3,519'5'5/12/2022 Open BEL_135U 4,209’4,214’3,607’3,611’5’09/15//21 Open BEL_135L 4,231’4,241’3,625’3,633’10‘9/17/21 Isolated T2 4,451'4,465'3,802'3,814'14'2/21/25 Open T2 4,501’4,517’3,843’3,856’16 07/30/20 Open TY3 4,517'4,537'3,856'3,872'20'2/21/25 Open TY3 4,561'4,567'3,891'3,896'6'2/21/25 Open T4 4,632’4,643’3,950’3,959’11 08/22/19 Open T5 4,654’4,661’3,968’3,974’7 07/30/20 Open T-5L 4,681’4,686’3,991’3,995’5‘9/15/21 Open T5A 4,714'4,720'4,018'4,023'6'2/21/25 Open T5A 4,731'4,737'4,032'4,037'6'2/21/25 Open T5B 4,793’4,799’4,085’4,090’6 07/30/20 Open T6 4,868'4,888'4,148'4,165'20'2/21/25 Open T6 4,909'4,915'4,183'4,188'6'2/21/25 Open T6A 4,984’4,994’4,246’4,254’10 07/30/20 Open T7 5,005'5,011'4,264'4,269'6'2/21/25 Open T8 5,058’5,078’4,308’4,325’20 08/22/19 Open T8 5,079’5,102’4,326’4,345’23’9/14/21 Open T8 5,102'5,108'4,345'4,350'6'2/21/25 Open (continued on following page) 4 T142 6 3 2 Bel 135 T2 Thru T18 Bel 105 Bel 120 Bel 133 Bel 132 Bel 131 Capillary String 3/12/25 3/8” 2205 Stainless Steel Top Bottom MD 0’ 3,780 TVD 0’ 3,259’ Updated by DMA 04-04-25 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 PERFORATION DETAIL (continued from previous page) Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T-9A 5,184’ 5,190’ 4,415’ 4,419’ 6‘ 9/14/21 Open T10 5,259’ 5,269’ 4,478’ 4,486’ 10 08/22/19 Open 5,276’ 5,286’ 4,492’ 4,501’ 10 08/22/19 Open T11 5,354’ 5,370’ 4,557’ 4,570 16 8/14/19 Open T-11A 5,386’ 5,404’ 4,583’ 4,597’ 14‘ 9/14/21 Open T12 5,520’ 5,545’ 4,692’ 4,713’ 30 03/15/19 Open T12 5,562’ 5,582’ 4,727’ 4,743’ 20 10/13/18 Isolated T17A 6,249’ 6,259’ 5,298’ 5,307’ 10 11/06/17 Isolated 6,259’ 6,265’ 5,307’ 5,312’ 6 12/14/17 Isolated 6,270’ 6,285’ 5,316’ 5,328’ 15 12/14/17 Isolated T18 6,418’ 6,433’ 5,440’ 5,452’ 15 02/07/18 Isolated T43 6,887’ 6,899’ 5,844’ 5,855’ 12 10/21/17 Isolated T142 8,767’ 8,777’ 7,677’ 7,687’ 10 10/13/17 Isolated T146 8,975’ 8,995’ 7,884’ 7,904’ 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,265'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0359242 / ADL0384372 / FEE-CIRI 217-028 50-133-20661-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,316' Size 120' 1,418' MD See Attached Schematic 2,980psi 6,890psi 120'120' 1,418' February 6, 2025 N/A 9,252' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINU Kalotsa 03CO 701C Same 8,160'4-1/2" ~1858 psi 9,252' See schematic Length Baker Swell Packer & N/A 1,280 (MD) / 1,203 (TVD) & N/A 8,173'5,555'4,721' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:48 am, Jan 17, 2025 325-016 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.01.17 10:08:49 - 09'00' Noel Nocas (4361) SFD 1/21/2025BJM 1/23/25 10-404 DSR-1/22/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.24 10:27:10 -09'00'01/24/25 RBDMS JSB 012425 Well Prognosis Well Name: Kalotsa 3 API Number: 50-133-20661-00-00 Current Status: Producing Gas Well Permit to Drill Number: 217-028 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2064 psi @ 4692’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 1858 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .74 psi/ft using 14.2 ppg EMW LOT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(.74-0.1) = 1858 psi / .64 = 2903‘ TVD Top of Applicable Gas Pool: 1555’ MD/1428’ TVD (Beluga-Tyonek) Well Status: Online Gas producer – 1030 mscfd, 3 bwpd, 40 psi FTP Brief Well Summary Kalotsa 3 was drilled and completed in July 2017 targeting the deep Tyonek sands. Multiple zones have been perforated over the years with a wide range of results. In 2019 perforations were added to the T4-T12 boosting rate to 1 mmscfd. Those perforations quickly declined and in July 2020 more perforations were added in the T2, T5 and T6 resulting in 2 mmscfd rate gain. Rate had fallen below 1 mmscfd by September 2021 when additional Tyonek sands were perforated along with the Bel 135 upper and lower. Those perfs came on wet and the BEL 135L was patched which boosted rate back up to 2 mmscfd. Rate had again declined below 1 mmscfd by May 2022 when multiple Beluga sands were perforated which boosted rate initially to ~2.8 mmscfd. The objective of this sundry is to add additional infill perforations to the Tyonek sands to increase the rate. Notes Regarding Wellbore Condition x Inclination o Max inclination = 36.98° at 4049’ MD o Max DLS: 5.53° @ 414’ MD x Min ID o 3.375” – (XSpan Permanent Patch at 4227’-4245’ MD) x Recent Tags o 11/25/22: RIH/w 2.5" DD bailer to 5401' SLM w/t to 5403' SLM (5420' RKB to 5422' RKB) POOH OOH/w full bailer thick course sand Pre-Sundry Steps: 1. RU slickline 2. PT lubricator to 250 psi low/ 2,500 psi high 3. D&T to TD w/ large OD drift to find updated tag and ensure wellbore is clean of any sand bridges. Last SL tag was 5422’ KB in November 2022. Note if fluid level is seen. 4. RDMO slickline Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate TY 2 – TY 8 sands from bottom up with 2-3/8” 60 deg phased perf guns: 1595 psi ? SFD 2492' TVD ? SFD Well Prognosis Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Btm MD Top TVD Btm TVD Footage TY_2 ±4,451' ±4,465' ±3,802' ±3,814' ±14' TY_3 ±4,517' ±4,537' ±3,856' ±3,872' ±20' TY_3 ±4,561' ±4,567' ±3,891' ±3,896' ±6' TY_5A ±4,714' ±4,720' ±4,018' ±4,023' ±6' TY_5A ±4,731' ±4,737' ±4,032' ±4,037' ±6' TY_6 ±4,868' ±4,888' ±4,148' ±4,165' ±20' TY_6 ±4,909' ±4,915' ±4,183' ±4,188' ±6' TY_7 ±5,005' ±5,011' ±4,264' ±4,269' ±6' TY_8 ±5,102' ±5,108' ±4,345' ±4,350' ±6' a. Proposed perfs are 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. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i.Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Updated by JLL 05/19/22 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ 1 16” 7-5/8” 4-1/2” No.Depth MD Depth TVD ID Item 1 1,280’ 1,203’ 3.958” Swell Packer 2 4,227’ 3,621’ 3.375” X-Span - Permanent Patch 4,227’-4,245’ 09/17/21 3 5,555’ 4,721’ CIBP 03/16/19 4 6,881’ 5,839’ 3.375” Permanent Patch 6,881’-6,903’ 11/06/17 5 8,760’ 7,670’ CIBP w/ 10’ of cement 10/21/17 6 8,950’ 7,859’ CIBP w/ 26’ cement 10/12/17 7 9,012’ 7,921’ CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875” Surf 1,418’ 4-1/2" Prod Csg 12.6 L-80 TXP 3.958” Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430’ MD. ToC at 1,180’ MD RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 7 T146 T147 T43 5 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL 105 3,813' 3,820' 3,286' 3,292' 7' 5/11/2022 Open BEL 120U 3,974' 3,992' 3,418' 3,433' 18' 5/11/2022 Open BEL 120M 3,995' 4,022' 3,435' 3,457' 27' 5/11/2022 Open BEL 120L 4,024' 4,030' 3,458' 3,463' 6' 5/11/2022 Open BEL 131 4,060' 4,067' 3,487' 3,493' 7' 5/12/2022 Open BEL 132 4,077' 4,081' 3,501' 3,504' 4' 5/12/2022 Open BEL 133 4,094' 4,099' 3,515' 3,519' 5' 5/12/2022 Open BEL_135U 4,209’ 4,214’ 3,607’ 3,611’ 5’ 09/15//21 Open BEL_135L 4,231’ 4,241’ 3,625’ 3,633’ 10‘ 9/17/21 Isolated T2 4,501’ 4,517’ 3,843’ 3,856’ 16 07/30/20 Open T4 4,632’ 4,643’ 3,950’ 3,959’ 11 08/22/19 Open T5 4,654’ 4,661’ 3,968’ 3,974’ 7 07/30/20 Open T-5L 4,681’ 4,686’ 3,991’ 3,995’ 5‘ 9/15/21 Open T5B 4,793’ 4,799’ 4,085’ 4,090’ 6 07/30/20 Open T6A 4,984’ 4,994’ 4,246’ 4,254’ 10 07/30/30 Open T8 5,058’ 5,078’ 4,308’ 4,325’ 20 08/22/19 Open T-8 5,079’ 5,102’ 4,326’ 4,345’ 23’ 9/14/21 Open T-9A 5,184’ 5,190’ 4,415’ 4,419’ 6‘ 9/14/21 Open T10 5,259’ 5,269’ 4,478’ 4,486’ 10 08/22/19 Open 5,276’ 5,286’ 4,492’ 4,501’ 10 08/22/19 Open T11 5,354’ 5,370’ 4,557’ 4,570 16 8/14/19 Open T-11A 5,386’ 5,404’ 4,583’ 4,597’ 14‘ 9/14/21 Open T12 5,520’ 5,545’ 4,692’ 4,713’ 30 03/15/19 Open 5,562’ 5,582’ 4,727’ 4,743’ 20 10/13/18 Isolated T17A 6,249’ 6,259’ 5,298’ 5,307’ 10 11/06/17 Isolated 6,259’ 6,265’ 5,307’ 5,312’ 6 12/14/17 Isolated 6,270’ 6,285’ 5,316’ 5,328’ 15 12/14/17 Isolated T18 6,418’ 6,433’ 5,440’ 5,452’ 15 02/07/18 Isolated T43 6,887’ 6,899’ 5,844’ 5,855’ 12 10/21/17 Isolated T142 8,767’ 8,777’ 7,677’ 7,687’ 10 10/13/17 Isolated T146 8,975’ 8,995’ 7,884’ 7,904’ 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated 4 T142 6 3 2 Bel 135 T2 Thru T18 Bel 105 Bel 120 Bel 133 Bel 132 Bel 131 Updated by SRW 1-16-25 PROPOSED Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ 1 16” 7-5/8” 4-1/2” No.Depth MD Depth TVD ID Item 1 1,280’1,203’3.958”Swell Packer 2 4,227’3,621’3.375”X-Span - Permanent Patch 4,227’-4,245’ 09/17/21 3 5,555’4,721’CIBP 03/16/19 4 6,881’5,839’3.375”Permanent Patch 6,881’-6,903’ 11/06/17 5 8,760’7,670’CIBP w/ 10’ of cement 10/21/17 6 8,950’7,859’CIBP w/ 26’ cement 10/12/17 7 9,012’7,921’CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875”Surf 1,418’ 4-1/2"Prod Csg 12.6 L-80 TXP 3.958”Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430’ MD. ToC at 1,180’ MD RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 7 T146 T147 T43 5 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft Date Status BEL 105 3,813'3,820'3,286'3,292'7'5/11/2022 Open BEL 120U 3,974'3,992'3,418'3,433'18'5/11/2022 Open BEL 120M 3,995'4,022'3,435'3,457'27'5/11/2022 Open BEL 120L 4,024'4,030'3,458'3,463'6'5/11/2022 Open BEL 131 4,060'4,067'3,487'3,493'7'5/12/2022 Open BEL 132 4,077'4,081'3,501'3,504'4'5/12/2022 Open BEL 133 4,094'4,099'3,515'3,519'5'5/12/2022 Open BEL_135U 4,209’4,214’3,607’3,611’5’09/15//21 Open BEL_135L 4,231’4,241’3,625’3,633’10‘9/17/21 Isolated TY_2 ±4,451'±4,465'±3,802'±3,814'±14'TBD Proposed T2 4,501’4,517’3,843’3,856’16 07/30/20 Open TY_3 ±4,517'±4,537'±3,856'±3,872'±20'TBD Proposed TY_3 ±4,561'±4,567'±3,891'±3,896'±6'TBD Proposed T4 4,632’4,643’3,950’3,959’11 08/22/19 Open T5 4,654’4,661’3,968’3,974’7 07/30/20 Open T-5L 4,681’4,686’3,991’3,995’5‘9/15/21 Open TY_5A ±4,714'±4,720'±4,018'±4,023'±6'TBD Proposed TY_5A ±4,731'±4,737'±4,032'±4,037'±6'TBD Proposed T5B 4,793’4,799’4,085’4,090’6 07/30/20 Open TY_6 ±4,868'±4,888'±4,148'±4,165'±20'TBD Proposed TY_6 ±4,909'±4,915'±4,183'±4,188'±6'TBD Proposed T6A 4,984’4,994’4,246’4,254’10 07/30/20 Open TY_7 ±5,005'±5,011'±4,264'±4,269'±6'TBD Proposed T8 5,058’5,078’4,308’4,325’20 08/22/19 Open T-8 5,079’5,102’4,326’4,345’23’9/14/21 Open TY_8 ±5,102'±5,108'±4,345'±4,350'±6'TBD Proposed T-9A 5,184’5,190’4,415’4,419’6‘9/14/21 Open T10 5,259’5,269’4,478’4,486’10 08/22/19 Open 5,276’5,286’4,492’4,501’10 08/22/19 Open T11 5,354’5,370’4,557’4,570 16 8/14/19 Open T-11A 5,386’5,404’4,583’4,597’14‘9/14/21 Open T12 5,520’5,545’4,692’4,713’30 03/15/19 Open Perforation Detail continued on pg. 2 4 T142 6 3 2 Bel 135 T2 Thru T18 Bel 105 Bel 120 Bel 133 Bel 132 Bel 131 Updated by SRW 1-16-25 PROPOSED Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 Perforation Detail continued from pg. 1 T12 5,562’ 5,582’ 4,727’ 4,743’ 20 10/13/18 Isolated T17A 6,249’ 6,259’ 5,298’ 5,307’ 10 11/06/17 Isolated 6,259’ 6,265’ 5,307’ 5,312’ 6 12/14/17 Isolated 6,270’ 6,285’ 5,316’ 5,328’ 15 12/14/17 Isolated T18 6,418’ 6,433’ 5,440’ 5,452’ 15 02/07/18 Isolated T43 6,887’ 6,899’ 5,844’ 5,855’ 12 10/21/17 Isolated T142 8,767’ 8,777’ 7,677’ 7,687’ 10 10/13/17 Isolated T146 8,975’ 8,995’ 7,884’ 7,904’ 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated 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: 05/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KALOTSA 3 (PTD 217-028) PERF 5/11/2022 Please include current contact information if different from above. PTD:217-028 T36648 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.25 10:54:10 -08'00' 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: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KALOTSA 3 (PTD 217-028) GPT 1/21/2022 Please include current contact information if different from above. 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/WϬϯͬϭϲͬϭϵ ϰ ϲ͕ϴϴϭ͛ ϱ͕ϴϯϵ͛ ϯ͘ϯϳϱ͟ WĞƌŵĂŶĞŶƚWĂƚĐŚϲ͕ϴϴϭ͛Ͳϲ͕ϵϬϯ͛ϭϭͬϬϲͬϭϳ ϱ ϴ͕ϳϲϬ͛ ϳ͕ϲϳϬ͛ /WǁͬϭϬ͛ŽĨĐĞŵĞŶƚϭϬͬϮϭͬϭϳ ϲ ϴ͕ϵϱϬ͛ ϳ͕ϴϱϵ͛ /WǁͬϮϲ͛ĐĞŵĞŶƚϭϬͬϭϮͬϭϳ ϳ ϵ͕ϬϭϮ͛ ϳ͕ϵϮϭ͛ /Wǁͬϱ͛ŽĨĐĞŵĞŶƚϵͬϭϬͬϭϳ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶ ƚŽ^ĞƚĞƉƚŚ ϴϰ yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟ ^ƵƌĨ ϭϮϬΖ ϳͲϱͬϴΗ ^ƵƌĨƐŐ Ϯϵ͘ϳ >ͲϴϬ d ϲ͘ϴϳϱ͟ ^ƵƌĨ ϭ͕ϰϭϴ͛ ϰͲϭͬϮΗ WƌŽĚƐŐ ϭϮ͘ϲ >ͲϴϬ dyW ϯ͘ϵϱϴ͟ ^ƵƌĨ ϵ͕ϮϱϮ͛ KWE,K>ͬDEdd/> ϳͲϱͬϴΗ ϵͲϳͬϴ͟ŚŽůĞ͗ϴϰ>ŽĨϭϮƉƉŐůĂƐƐůĞĂĚĂŶĚϯϲ>Ɛϭϱ͘ϰƉƉŐůĂƐƐ'ƚĂŝů͘ϭϬϬй ƌĞƚƵƌŶƐƚŚƌŽƵŐŚŽƵƚ͕ϯϬďďůƐƚŽƐƵƌĨĂĐĞ͘ ϰͲϭͬϮ͟ ϲͲϯͬϰ͟ŚŽůĞ͗ϮϰϬ>ϭϮ͘ϱƉƉŐdǇƉĞ/Ͳ//ĐĞŵĞŶƚ͕ĨŽůůŽǁĞĚǁŝƚŚϯϮ>ŽĨůĂƐƐ'ƚĂŝů͘ >ŽƐƚϲϯďďůƐĚƵƌŝŶŐũŽď͕ϯďďůƐŽĨƐƉĂĐĞƌƌĞƚƵƌŶĞĚƚŽƐƵƌĨĂĐĞ͘ϳͬϴͬϭϳ^DdƐŚŽǁƐ ƐŽůŝĚĐĞŵĞŶƚƵƉƚŽϭ͕ϰϯϬ͛D͘dŽĂƚϭ͕ϭϴϬ͛D ZΛϯ͕ϵϴϳ͛ ZΛϱ͕ϰϯϴ͛ ZΛϲ͕ϰϳϰ͛ ZΛϳ͕ϰϳϬ͛ dϭϰϲ dϭϰϳ dϰϯ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &ƚ ĂƚĞ ^ƚĂƚƵƐ >ͺϭϯϱh ϰ͕ϮϬϵ͛ ϰ͕Ϯϭϰ͛ ϯ͕ϲϬϳ͛ ϯ͕ϲϭϭ͛ ϱ͛ ϬϵͬϭϱͬͬϮϭ KƉĞŶ >ͺϭϯϱ> ϰ͕Ϯϯϭ͛ ϰ͕Ϯϰϭ͛ ϯ͕ϲϮϱ͛ ϯ͕ϲϯϯ͛ ϭϬ͚ ϵͬϭϳͬϮϭ /ƐŽůĂƚĞĚ dϮ ϰ͕ϱϬϭ͛ ϰ͕ϱϭϳ͛ ϯ͕ϴϰϯ͛ ϯ͕ϴϱϲ͛ ϭϲ ϬϳͬϯϬͬϮϬ KƉĞŶ dϰ ϰ͕ϲϯϮ͛ ϰ͕ϲϰϯ͛ ϯ͕ϵϱϬ͛ ϯ͕ϵϱϵ͛ ϭϭ ϬϴͬϮϮͬϭϵ KƉĞŶ dϱ ϰ͕ϲϱϰ͛ ϰ͕ϲϲϭ͛ ϯ͕ϵϲϴ͛ ϯ͕ϵϳϰ͛ ϳ ϬϳͬϯϬͬϮϬ KƉĞŶ dͲϱ> ϰ͕ϲϴϭ͛ ϰ͕ϲϴϲ͛ ϯ͕ϵϵϭ͛ ϯ͕ϵϵϱ͛ ϱ͚ ϵͬϭϱͬϮϭ KƉĞŶ dϱ ϰ͕ϳϵϯ͛ ϰ͕ϳϵϵ͛ ϰ͕Ϭϴϱ͛ ϰ͕ϬϵϬ͛ ϲ ϬϳͬϯϬͬϮϬ KƉĞŶ dϲ ϰ͕ϵϴϰ͛ ϰ͕ϵϵϰ͛ ϰ͕Ϯϰϲ͛ ϰ͕Ϯϱϰ͛ ϭϬ ϬϳͬϯϬͬϯϬ KƉĞŶ dϴ ϱ͕Ϭϱϴ͛ ϱ͕Ϭϳϴ͛ ϰ͕ϯϬϴ͛ ϰ͕ϯϮϱ͛ ϮϬ ϬϴͬϮϮͬϭϵ KƉĞŶ dͲϴ ϱ͕Ϭϳϵ͛ ϱ͕ϭϬϮ͛ ϰ͕ϯϮϲ͛ ϰ͕ϯϰϱ͛ Ϯϯ͛ ϵͬϭϰͬϮϭ KƉĞŶ dͲϵ ϱ͕ϭϴϰ͛ ϱ͕ϭϵϬ͛ ϰ͕ϰϭϱ͛ ϰ͕ϰϭϵ͛ ϲ͚ ϵͬϭϰͬϮϭ KƉĞŶ dϭϬ ϱ͕Ϯϱϵ͛ ϱ͕Ϯϲϵ͛ ϰ͕ϰϳϴ͛ ϰ͕ϰϴϲ͛ ϭϬ ϬϴͬϮϮͬϭϵ KƉĞŶ ϱ͕Ϯϳϲ͛ ϱ͕Ϯϴϲ͛ ϰ͕ϰϵϮ͛ ϰ͕ϱϬϭ͛ ϭϬ ϬϴͬϮϮͬϭϵ KƉĞŶ dϭϭ ϱ͕ϯϱϰ͛ ϱ͕ϯϳϬ͛ ϰ͕ϱϱϳ͛ ϰ͕ϱϳϬ ϭϲ ϴͬϭϰͬϭϵ KƉĞŶ dͲϭϭ ϱ͕ϯϴϲ͛ ϱ͕ϰϬϰ͛ ϰ͕ϱϴϯ͛ ϰ͕ϱϵϳ͛ ϭϰ͚ ϵͬϭϰͬϮϭ KƉĞŶ dϭϮ ϱ͕ϱϮϬ͛ ϱ͕ϱϰϱ͛ ϰ͕ϲϵϮ͛ ϰ͕ϳϭϯ͛ ϯϬ Ϭϯͬϭϱͬϭϵ KƉĞŶ ϱ͕ϱϲϮ͛ ϱ͕ϱϴϮ͛ ϰ͕ϳϮϳ͛ ϰ͕ϳϰϯ͛ ϮϬ ϭϬͬϭϯͬϭϴ /ƐŽůĂƚĞĚ dϭϳ ϲ͕Ϯϰϵ͛ ϲ͕Ϯϱϵ͛ ϱ͕Ϯϵϴ͛ ϱ͕ϯϬϳ͛ ϭϬ ϭϭͬϬϲͬϭϳ /ƐŽůĂƚĞĚ ϲ͕Ϯϱϵ͛ ϲ͕Ϯϲϱ͛ ϱ͕ϯϬϳ͛ ϱ͕ϯϭϮ͛ ϲ ϭϮͬϭϰͬϭϳ /ƐŽůĂƚĞĚ ϲ͕ϮϳϬ͛ ϲ͕Ϯϴϱ͛ ϱ͕ϯϭϲ͛ ϱ͕ϯϮϴ͛ ϭϱ ϭϮͬϭϰͬϭϳ /ƐŽůĂƚĞĚ dϭϴ ϲ͕ϰϭϴ͛ ϲ͕ϰϯϯ͛ ϱ͕ϰϰϬ͛ ϱ͕ϰϱϮ͛ ϭϱ ϬϮͬϬϳͬϭϴ /ƐŽůĂƚĞĚ dϰϯ ϲ͕ϴϴϳ͛ ϲ͕ϴϵϵ͛ ϱ͕ϴϰϰ͛ ϱ͕ϴϱϱ͛ ϭϮ ϭϬͬϮϭͬϭϳ /ƐŽůĂƚĞĚ dϭϰϮ ϴ͕ϳϲϳ͛ ϴ͕ϳϳϳ͛ ϳ͕ϲϳϳ͛ ϳ͕ϲϴϳ͛ ϭϬ ϭϬͬϭϯͬϭϳ /ƐŽůĂƚĞĚ dϭϰϲ ϴ͕ϵϳϱ͛ ϴ͕ϵϵϱ͛ ϳ͕ϴϴϰ͛ ϳ͕ϵϬϰ͛ ϮϬ ϬϵͬϮϲͬϭϳ /ƐŽůĂƚĞĚ dϭϰϳ ϵ͕ϬϮϮΖ ϵ͕ϬϯϯΖ ϳ͕ϵϯϭΖ ϳ͕ϵϰϮΖ ϭϭ ϬϳͬϮϳͬϭϳ /ƐŽůĂƚĞĚ dϭϰϮ dϮ dŚƌƵ dϭϴ Ğůϭϯϱ hƉĚĂƚĞĚďǇ:>>ϬϱͬϬϮͬϮϮ WZKWK^ <ĂůŽƚƐĂηϯ Wd͗ϮϭϳͲϬϮϴ W/͗ϱϬͲϭϯϯͲϮϬϲϲϭͲϬϬ Wdсϱ͕ϱϱϱ͛ͬWdsсϰ͕ϳϮϭ͛ dсϵ͕Ϯϲϱ͛ͬdsсϴ͕ϭϳϯ͛ Z<ƚŽ'>сϭϵ͘ϭ͛ ϭϲ͟ ϳͲϱͬϴ͟ ϰͲϭͬϮ͟ EŽ͘ĞƉƚŚ D ĞƉƚŚ ds/ /ƚĞŵ ϭ ϭ͕ϮϴϬ͛ ϭ͕ϮϬϯ͛ ϯ͘ϵϱϴ͟ ^ǁĞůůWĂĐŬĞƌ Ϯ ϰ͕ϮϮϳ͛ ϯ͕ϲϮϭ͛ ϯ͘ϯϳϱ͟ yͲ^ƉĂŶͲWĞƌŵĂŶĞŶƚWĂƚĐŚϰ͕ϮϮϳ͛Ͳϰ͕Ϯϰϱ͛ϬϵͬϭϳͬϮϭ ϯ ϱ͕ϱϱϱ͛ ϰ͕ϳϮϭ͛ /WϬϯͬϭϲͬϭϵ ϰ ϲ͕ϴϴϭ͛ ϱ͕ϴϯϵ͛ ϯ͘ϯϳϱ͟ WĞƌŵĂŶĞŶƚWĂƚĐŚϲ͕ϴϴϭ͛Ͳϲ͕ϵϬϯ͛ϭϭͬϬϲͬϭϳ ϱ ϴ͕ϳϲϬ͛ ϳ͕ϲϳϬ͛ /WǁͬϭϬ͛ŽĨĐĞŵĞŶƚϭϬͬϮϭͬϭϳ ϲ ϴ͕ϵϱϬ͛ ϳ͕ϴϱϵ͛ /WǁͬϮϲ͛ĐĞŵĞŶƚϭϬͬϭϮͬϭϳ ϳ ϵ͕ϬϭϮ͛ ϳ͕ϵϮϭ͛ /Wǁͬϱ͛ŽĨĐĞŵĞŶƚϵͬϭϬͬϭϳ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶ ƚŽ^ĞƚĞƉƚŚ ϴϰ yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟ ^ƵƌĨ ϭϮϬΖ ϳͲϱͬϴΗ ^ƵƌĨƐŐ Ϯϵ͘ϳ >ͲϴϬ d ϲ͘ϴϳϱ͟ ^ƵƌĨ ϭ͕ϰϭϴ͛ ϰͲϭͬϮΗ WƌŽĚƐŐ ϭϮ͘ϲ >ͲϴϬ dyW ϯ͘ϵϱϴ͟ ^ƵƌĨ ϵ͕ϮϱϮ͛ KWE,K>ͬDEdd/> ϳͲϱͬϴΗ ϵͲϳͬϴ͟ŚŽůĞ͗ϴϰ>ŽĨϭϮƉƉŐůĂƐƐůĞĂĚĂŶĚϯϲ>Ɛϭϱ͘ϰƉƉŐůĂƐƐ'ƚĂŝů͘ϭϬϬй ƌĞƚƵƌŶƐƚŚƌŽƵŐŚŽƵƚ͕ϯϬďďůƐƚŽƐƵƌĨĂĐĞ͘ ϰͲϭͬϮ͟ ϲͲϯͬϰ͟ŚŽůĞ͗ϮϰϬ>ϭϮ͘ϱƉƉŐdǇƉĞ/Ͳ//ĐĞŵĞŶƚ͕ĨŽůůŽǁĞĚǁŝƚŚϯϮ>ŽĨůĂƐƐ'ƚĂŝů͘ >ŽƐƚϲϯďďůƐĚƵƌŝŶŐũŽď͕ϯďďůƐŽĨƐƉĂĐĞƌƌĞƚƵƌŶĞĚƚŽƐƵƌĨĂĐĞ͘ϳͬϴͬϭϳ^DdƐŚŽǁƐ ƐŽůŝĚĐĞŵĞŶƚƵƉƚŽϭ͕ϰϯϬ͛D͘dŽĂƚϭ͕ϭϴϬ͛D ZΛϯ͕ϵϴϳ͛ ZΛϱ͕ϰϯϴ͛ ZΛϲ͕ϰϳϰ͛ ZΛϳ͕ϰϳϬ͛ dϭϰϲ dϭϰϳ dϰϯ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &ƚ ĂƚĞ ^ƚĂƚƵƐ >ϭϬϱʹ >ϭϯϯ цϯ͕ϴϭϯ͛ цϰ͕Ϭϵϵ͛ цϯ͕Ϯϴϲ͛ цϯ͕ϱϭϵ͛ цϯϴϲ͛ &hdhZ WZKWK^ >ͺϭϯϱh ϰ͕ϮϬϵ͛ ϰ͕Ϯϭϰ͛ ϯ͕ϲϬϳ͛ ϯ͕ϲϭϭ͛ ϱ͛ ϬϵͬϭϱͬͬϮϭ KƉĞŶ >ͺϭϯϱ> ϰ͕Ϯϯϭ͛ ϰ͕Ϯϰϭ͛ ϯ͕ϲϮϱ͛ ϯ͕ϲϯϯ͛ ϭϬ͚ ϵͬϭϳͬϮϭ /ƐŽůĂƚĞĚ dϮ ϰ͕ϱϬϭ͛ ϰ͕ϱϭϳ͛ ϯ͕ϴϰϯ͛ ϯ͕ϴϱϲ͛ ϭϲ ϬϳͬϯϬͬϮϬ KƉĞŶ dϰ ϰ͕ϲϯϮ͛ ϰ͕ϲϰϯ͛ ϯ͕ϵϱϬ͛ ϯ͕ϵϱϵ͛ ϭϭ ϬϴͬϮϮͬϭϵ KƉĞŶ dϱ ϰ͕ϲϱϰ͛ ϰ͕ϲϲϭ͛ ϯ͕ϵϲϴ͛ ϯ͕ϵϳϰ͛ ϳ ϬϳͬϯϬͬϮϬ KƉĞŶ dͲϱ> ϰ͕ϲϴϭ͛ ϰ͕ϲϴϲ͛ ϯ͕ϵϵϭ͛ ϯ͕ϵϵϱ͛ ϱ͚ ϵͬϭϱͬϮϭ KƉĞŶ dϱ ϰ͕ϳϵϯ͛ ϰ͕ϳϵϵ͛ ϰ͕Ϭϴϱ͛ ϰ͕ϬϵϬ͛ ϲ ϬϳͬϯϬͬϮϬ KƉĞŶ dϲ ϰ͕ϵϴϰ͛ ϰ͕ϵϵϰ͛ ϰ͕Ϯϰϲ͛ ϰ͕Ϯϱϰ͛ ϭϬ ϬϳͬϯϬͬϯϬ KƉĞŶ dϴ ϱ͕Ϭϱϴ͛ ϱ͕Ϭϳϴ͛ ϰ͕ϯϬϴ͛ ϰ͕ϯϮϱ͛ ϮϬ ϬϴͬϮϮͬϭϵ KƉĞŶ dͲϴ ϱ͕Ϭϳϵ͛ ϱ͕ϭϬϮ͛ ϰ͕ϯϮϲ͛ ϰ͕ϯϰϱ͛ Ϯϯ͛ ϵͬϭϰͬϮϭ KƉĞŶ dͲϵ ϱ͕ϭϴϰ͛ ϱ͕ϭϵϬ͛ ϰ͕ϰϭϱ͛ ϰ͕ϰϭϵ͛ ϲ͚ ϵͬϭϰͬϮϭ KƉĞŶ dϭϬ ϱ͕Ϯϱϵ͛ ϱ͕Ϯϲϵ͛ ϰ͕ϰϳϴ͛ ϰ͕ϰϴϲ͛ ϭϬ ϬϴͬϮϮͬϭϵ KƉĞŶ ϱ͕Ϯϳϲ͛ ϱ͕Ϯϴϲ͛ ϰ͕ϰϵϮ͛ ϰ͕ϱϬϭ͛ ϭϬ ϬϴͬϮϮͬϭϵ KƉĞŶ dϭϭ ϱ͕ϯϱϰ͛ ϱ͕ϯϳϬ͛ ϰ͕ϱϱϳ͛ ϰ͕ϱϳϬ ϭϲ ϴͬϭϰͬϭϵ KƉĞŶ dͲϭϭ ϱ͕ϯϴϲ͛ ϱ͕ϰϬϰ͛ ϰ͕ϱϴϯ͛ ϰ͕ϱϵϳ͛ ϭϰ͚ ϵͬϭϰͬϮϭ KƉĞŶ dϭϮ ϱ͕ϱϮϬ͛ ϱ͕ϱϰϱ͛ ϰ͕ϲϵϮ͛ ϰ͕ϳϭϯ͛ ϯϬ Ϭϯͬϭϱͬϭϵ KƉĞŶ ϱ͕ϱϲϮ͛ ϱ͕ϱϴϮ͛ ϰ͕ϳϮϳ͛ ϰ͕ϳϰϯ͛ ϮϬ ϭϬͬϭϯͬϭϴ /ƐŽůĂƚĞĚ dϭϳ ϲ͕Ϯϰϵ͛ ϲ͕Ϯϱϵ͛ ϱ͕Ϯϵϴ͛ ϱ͕ϯϬϳ͛ ϭϬ ϭϭͬϬϲͬϭϳ /ƐŽůĂƚĞĚ ϲ͕Ϯϱϵ͛ ϲ͕Ϯϲϱ͛ ϱ͕ϯϬϳ͛ ϱ͕ϯϭϮ͛ ϲ ϭϮͬϭϰͬϭϳ /ƐŽůĂƚĞĚ ϲ͕ϮϳϬ͛ ϲ͕Ϯϴϱ͛ ϱ͕ϯϭϲ͛ ϱ͕ϯϮϴ͛ ϭϱ ϭϮͬϭϰͬϭϳ /ƐŽůĂƚĞĚ dϭϴ ϲ͕ϰϭϴ͛ ϲ͕ϰϯϯ͛ ϱ͕ϰϰϬ͛ ϱ͕ϰϱϮ͛ ϭϱ ϬϮͬϬϳͬϭϴ /ƐŽůĂƚĞĚ dϰϯ ϲ͕ϴϴϳ͛ ϲ͕ϴϵϵ͛ ϱ͕ϴϰϰ͛ ϱ͕ϴϱϱ͛ ϭϮ ϭϬͬϮϭͬϭϳ /ƐŽůĂƚĞĚ dϭϰϮ ϴ͕ϳϲϳ͛ ϴ͕ϳϳϳ͛ ϳ͕ϲϳϳ͛ ϳ͕ϲϴϳ͛ ϭϬ ϭϬͬϭϯͬϭϳ /ƐŽůĂƚĞĚ dϭϰϲ ϴ͕ϵϳϱ͛ ϴ͕ϵϵϱ͛ ϳ͕ϴϴϰ͛ ϳ͕ϵϬϰ͛ ϮϬ ϬϵͬϮϲͬϭϳ /ƐŽůĂƚĞĚ dϭϰϳ ϵ͕ϬϮϮΖ ϵ͕ϬϯϯΖ ϳ͕ϵϯϭΖ ϳ͕ϵϰϮΖ ϭϭ ϬϳͬϮϳͬϭϳ /ƐŽůĂƚĞĚ dϭϰϮ Ğůϭϯϱ >ϭϬϱ dŚƌƵ >ϭϯϯ dϮ dŚƌƵ dϭϴ 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,265 feet See schematic feet true vertical 8,173 feet N/A feet Effective Depth measured 5,555 feet 1,280 feet true vertical 4,721 feet 1,203 feet Perforation depth Measured depth 4,501 - 5,545 feet True Vertical depth 3,625 - 4,713'feet Tubing (size, grade, measured and true vertical depth)N/A 1,280 (MD) Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr 1,203 (TVD) SSSV: NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: 7,500psi 2,980psi 6,890psi 8,430psi Burst Collapse 1,410psi 4,790psi 120' 1,316' 8,160'9,252'4-1/2" measuredPlugs Junk measured N/A Length 120' 1,418' Size Conductor Surface Intermediate 16" 7-5/8" Production Liner 9,252' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-028 50-133-20661-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: CO61505 SHL / ADL359242 / ADL384372 TPH/BHL / Fee CIRI Ninilchik Field / Beluga/Tyonek Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Kalotsa 03 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 001,849 0 86 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 120' 1,418' N/A 0 Structural TVD 321-440 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 836 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 128 Ryan Rupert ryan.rupert@hilcorp.com (907) 777-8503 L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 12:45 pm, Nov 23, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.23 11:08:26 -09'00' Dan Marlowe (1267) DSR-11/23/21SFD 11/29/2021 RBDMS HEW 11/24/2021 BJM 12/1/21 Updated by JLL 11/21/21 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ 1 16” 7-5/8” 4-1/2” No.Depth MD Depth TVD ID Item 1 1,280’ 1,203’ 3.958” Swell Packer 2 4,227’ 3,621’ 3.375” X-Span - Permanent Patch 4,227’-4,245’ 09/17/21 3 5,555’ 4,721’ CIBP 03/16/19 4 6,881’ 5,839’ 3.375” Permanent Patch 6,881’-6,903’ 11/06/17 5 8,760’ 7,670’ CIBP w/ 10’ of cement 10/21/17 6 8,950’ 7,859’ CIBP w/ 26’ cement 10/12/17 7 9,012’ 7,921’ CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875” Surf 1,418’ 4-1/2" Prod Csg 12.6 L-80 TXP 3.958” Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430’ MD. ToC at 1,180’ MD RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 7 T146 T147 T43 5 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL_135U 4,209’ 4,214’ 3,607’ 3,611’ 5’ 09/15//21 Open BEL_135L 4,231’ 4,241’ 3,625’ 3,633’ 10‘ 9/17/21 Isolated T2 4,501’ 4,517’ 3,843’ 3,856’ 16 07/30/20 Open T4 4,632’ 4,643’ 3,950’ 3,959’ 11 08/22/19 Open T5 4,654’ 4,661’ 3,968’ 3,974’ 7 07/30/20 Open T-5L 4,681’ 4,686’ 3,991’ 3,995’ 5‘ 9/15/21 Open T5B 4,793’ 4,799’ 4,085’ 4,090’ 6 07/30/20 Open T6A 4,984’ 4,994’ 4,246’ 4,254’ 10 07/30/30 Open T8 5,058’ 5,078’ 4,308’ 4,325’ 20 08/22/19 Open T-8 5,079’ 5,102’ 4,326’ 4,345’ 23’ 9/14/21 Open T-9A 5,184’ 5,190’ 4,415’ 4,419’ 6‘ 9/14/21 Open T10 5,259’ 5,269’ 4,478’ 4,486’ 10 08/22/19 Open 5,276’ 5,286’ 4,492’ 4,501’ 10 08/22/19 Open T11 5,354’ 5,370’ 4,557’ 4,570 16 8/14/19 Open T-11A 5,386’ 5,404’ 4,583’ 4,597’ 14‘ 9/14/21 Open T12 5,520’ 5,545’ 4,692’ 4,713’ 30 03/15/19 Open 5,562’ 5,582’ 4,727’ 4,743’ 20 10/13/18 Isolated T17A 6,249’ 6,259’ 5,298’ 5,307’ 10 11/06/17 Isolated 6,259’ 6,265’ 5,307’ 5,312’ 6 12/14/17 Isolated 6,270’ 6,285’ 5,316’ 5,328’ 15 12/14/17 Isolated T18 6,418’ 6,433’ 5,440’ 5,452’ 15 02/07/18 Isolated T43 6,887’ 6,899’ 5,844’ 5,855’ 12 10/21/17 Isolated T142 8,767’ 8,777’ 7,677’ 7,687’ 10 10/13/17 Isolated T146 8,975’ 8,995’ 7,884’ 7,904’ 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated4 T142 6 3 2 T-8 5,079’ 5,102’ 4,326’ 4,345’ 23’ 9/14/21 Open T-9A 5,184’ 5,190’ 4,415’ 4,419’ 6‘ 9/14/21 Openp p( ) ( ) p( ) ( ) BEL_135U 4,209’ 4,214’ 3,607’ 3,611’ 5’ 09/15//21 Open BEL_135L 4,231’ 4,241’ 3,625’ 3,633’ 10‘ 9/17/21 Isolated Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T-5L 4,681’ 4,686’ 3,991’ 3,995’ 5‘ 9/15/21 Open ,, ,, //p T-11A 5,386’ 5,404’ 4,583’ 4,597’ 14‘ 9/14/21 Open p // Rig Start Date End Date E-Line 9/14/21 11/1/21 11/01/2021 - Monday Met with Reservoir engineer. Production has stayed over 1MM since initial perf adds. Decided that there is no need for additional perfs at this time. 09/14/2021- Tuesday RIH W/ GPT TOOL FLUID LOOKED TO START PERCULATE @1450' BUT CAME IN GOOD @ 4380'. TAGGED BOTTOM @ 5541.5'. RIH w/ 14' AND 6' 2 7/8" 6SPF HSC ON SWITCHES, PULLED LOG, SENT TO TOWN AND GOT THE GUNS IN POSITION TO SHOOT THE 14' GUN IN THE T-11A. SHOT FIRST CAP @ 5386-5400' CAP WENT OFF NO CHANGE IN RATE OR PRESSURE PULLED INTO POSITION ON 6' IN THE T-9A SAND SENT LOGS AND SHOT @ 5184-5190 NO CHANGE. GUNS DID NOT FIRE. LOOKED LIKE PRIMERCORD LOW ORDERED. When POOH, rate jumped up from 825mcfd to 1175mcfd. RIH W/ 14' AND 6' HSC ON SWITCHES RAN LOGS AND SENT TO TOWN, PULLED INTO POSITION AND SHOT T-11A @ 5386-5404'. Prior rate at 1050mcfd. Rate jumped up to 1200MCFD. LOGGED FOR GUN #2 AND PULLED INTO POSITION SHOT THE T-9 SAND @ 5184-5190' MD. Rate up to 1590mcfd. RIH W/ 23' X 2 7/8" 6SPF HSC, PULLED LOG & SENT TO TOWN, POSITIONED GUNS TO SHOOT THE T-8 SAND SHOT @ 5079'-5102'. Base rate at 1550mcfd. Rate up to 1700mcfd while POOH. AK E line arrive on location. PTW, JSA with crews. Fox energy N2 pump and Air liquid N2 tank arrive on location. SIMOPS. Spot in equipment. Make up lubricator. and Wire line valves. Rig up N2 pump and 1502 iron to E-line pump in sub on tree. Make up Rope socket and 12' weight bar, GPT tool. Cool down N2. PT lubricator 250/2,500 psi. RIH and tag at 5,077'. Pick up and tag again to confirm solid tag depth. LOG OOH up to 3,940'. Found fluid level at 4,464'. POOH to surface. No N2 used. Told Fox N2 to rig down and depart location. At surface. Change out AK E-line BHA. MU rope socket, Gamma, 3-1/4" setting tool and 17.9' patch assembly. RIH to 4,320' and log correlation pass. Send to town engineers. Place patch across BEL_135L sands at 4,231'- 4,241' . CCL depth 4,210.7'. CCL to top of patch is 16.3' Top of patch is at 4,227' bottom of patch is at 4,244.9'. Prior to setting patch weight was 1,210 lbs. Setting took 3.5 minutes to set and saw weight drop 737 lbs. POOH to surface. Close swab. Bleed down setting tool and rig down. Turn well over to production. SITP was 480 psi. Joe Brady X-span permanent patch. Daily Operations: Hilcorp Alaska, LLC. Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 3 50-133-20661-00-00 217-028 09/15/2021 - Wednesday RIH W/ 2-7/8" 6SPF HSC SWITCH GUNS, 5' / 10' / 5' LOGGED AND SENT TO TOWN FOR CORRELATION ON GUN #4 (T-5L). Shot T- 5L from 4,681'-4,686' MD. Base rate was 1,600MCFD. No change in rate. LOGGED UP TO SHOOT THE BEL135 UPPER AND LOWER SENT TO TOWN, SHOT BEL 135L @ 4,231'-4,241' AND THE BEL 135U @ 4,209'-4,214' within minutes of each other. base rate was 1,600mcfd. After shot, rate falls to 0mcfd within minutes. RIH W/ GPT TOOL FOUND FLUID @ 2,960' AND TAGGED TD @ 5,497', STBY, LOGGED UP TO TOP OF PERFS, STBY, THEN LOGGED TO SURFACE @ 30FPM OH RIGGING DOWN. 09/17/2021- Friday Place patch across BEL_135L sands at 4,231'- 4,241' . Shot T- 5L from 4,681'-4,686' MD. SHOT BEL 135L @ 4,231'-4,241' AND THE BEL 135U @ 4,209'-4,214' T-8 SAND SHOT @ 5079'-5102'. B SHOT T-11A @ 5386-5404' SHOT THE T-9 SAND @ 5184-5190' MD. Top of patch is at 4,227' bottom of patch is at 4,244.9' GUNS DID NOT FIRE. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/09/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KALOTSA 3 (PTD 217-028) GPT/PERF 09/14/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/09/2021 By Abby Bell at 4:28 pm, Nov 09, 2021 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 / Patch____ 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): Ninilchik Field - Beluga/Tyonek Gas pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,265'n/a Casing Collapse Structural Conductor 1410 psi Surface 4790 psi Intermediate Production 7500 psi 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: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 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 ryan.rupert @hilcorp.com 8,173'5,555'4721'~1659 psi see schematic Baker swell Packer, n/a 1280' MD / 1203' TVD; NA Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 C061505 SHL / ADL359242 / ADL384372 TPH/BHL / FEE CIRI 217-028 50-133-20661-00-00 Kalotsa-03 Length Size CO 701C Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY n/a TVD Burst n/a 8430 psi MD 2980 psi 6890 psi 120' 1,316' 120' 1,418' 8,160'4-1/2" 16" 7-5/8" 120' 1,418' 9,252' Perforation Depth MD (ft): See Attached Schematic 9,252' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 16, 2021 n/a Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:46 am, Sep 01, 2021 321-440 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.31 17:06:00 -08'00' Taylor Wellman (2143) 10-404 SFD 9/1/2021BJM 9/9/21 DSR-9/9/21 dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 14:32:19 -08'00' RBDMS HEW 9/13/2021 Well: Kalotsa-03 Date: 8/31/2021 Well Name:Kalotsa-03 API Number:50-133-20661-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:217-028 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Todd Sidoti (907) 632-4113 (C) Max. Expected BHP:~ 2,131 psi @ 4713’ TVD Based on 0.452 psi/ft to deepest open sand (T-12) Max. Potential Surface Pressure ~ 1,659 psi Based on 0.1 psi/ft to surface Well Summary Kalotsa-03 had been a steady ~500mcfd well until perfs were added in July-2020. The FL before perfs were added was found at ~5275’ MD. The rate shot up to over 2500mcfd. The well hasn’t shown any water production before or after these perfs. The rate has now fallen to <900mcfd. Kalotsa-03 has several unshot Beluga and Tyonek sands. All proposed perfs are within the same pool. The goal of this project is to perforate additional Beluga and Tyonek sands to increase production from the well. Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Max Inclination = 37 degrees at 4050’ MD x Recent history o 7/30/20: 1-11/16” GPT tagged at 5555’ MD and found a fluid-y mix from 5275 and below 2-7/8” x 16’ perf gun went down to 4517’ MD. Shot flowing o 8/23/19: GPT tagged at 5552’ MD and found a fluid from 5444’ MD and below 2-7/8” x 10’ perf gun went down to 5286’ MD Nitrogen Risk 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 Proposed perforations fall within the Beluga/Tyonek Gas Pool as defined in CO 701C. SFD 9/1/2021 Well: Kalotsa-03 Date: 8/31/2021 E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,500 psi High 3. Rig up perf gun and GPT (Likely 2-7/8” – 3-3/8” 4-6 spf) 4. RIH, depetmine FL and obtain a tag of PBTD. 5. Perforate the sands listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) BEL_55 ±2,523'±2,544'±2,225'±2,243'22' BEL_59 ±2,737'±2,761'±2,400'±2,421'25' BEL_60 ±2,806'±2,828'±2,458'±2,475'22' BEL_65 ±2,844'±2,876'±2,489'±2,516'33' BEL_70 ±2,887'±2,916'±2,524'±2,549'30' BEL_92-6 ±3,426'±3,440'±2,967'±2,979'14' BEL_98 ±3,656'±3,675'±3,156'±3,171'19' BEL_105 ±3,811'±3,821'±3,284'±3,293'10' BEL_110 ±3,863'±3,875'±3,328'±3,337'12' BEL_120 ±3,970'±3,994'±3,415'±3,434'25' BEL_131 ±4,058'±4,068'±3,485'±3,494'11' BEL_132 ±4,075'±4,100'±3,499'±3,519'25' BEL_134 ±4,114'±4,120'±3,531'±3,535'6' BEL_135 ±4,209'±4,215'±3,606'±3,611'6' BEL_135 ±4,230'±4,253'±3,624'±3,642'23' BEL_135 ±4,273'±4,299'±3,659'±3,680'26' T-5 ±4,654'±4,663'±3,968'±3,975'10' T-5 ±4,679'±4,686'±3,988'±3,994'7' T-5B ±4,787'±4,799'±4,079'±4,090'12' T-6A ±4,980'±4,994'±4,243'±4,254'14' T-8 ±5,079'±5,103'±4,326'±4,346'24' T-9A ±5,182'±5,192'±4,412'±4,421'11' T-11A ±5,385'±5,405'±4,582'±4,598'20' Consult with OE for what WHP’s to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Matt Petrowsky (Geo): 814-421-6753 ii. Anthony McConkey (RE): 529-6199 6. RD E-Line Unit and turn well over to production. Well: Kalotsa-03 Date: 8/31/2021 Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 3,500 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 4-1/2” patch or plug 5. RIH and set plug or patch per OE. 6. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations Updated by CRR 08-31-21 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ 1 16” 7-5/8” 4-1/2” No.Depth ID Item 1 1,280’3.958”Swell Packer 2 5,555’CIBP 03/16/19 3 6,881’3.375”Permanent Patch 6,881’-6,903’ 11/06/17 4 8,760’CIBP w/ 10’ of cement 10/21/17 5 8,950’CIBP w/ 26’ cement 10/12/17 6 9,012’CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875”Surf 1,418’ 4-1/2"Prod Csg 12.6 L-80 TXP 3.958”Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430’ MD. ToC at 1,180’ MD RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 6 T146 T147 T43 4 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft Date Status T2 4,501’4,517’3,843’3,856’16 07/30/20 Open T4 4,632’4,643’3,950’3,959’11 08/22/19 Open T5 4,654’4,661’3,968’3,974’7 07/30/20 Open T5B 4,793’4,799’4,085’4,090’6 07/30/20 Open T6A 4,984’4,994’4,246’4,254’10 07/30/30 Open T8 5,058’5,078’4,308’4,325’20 08/22/19 Open T10 5,259’5,269’4,478’4,486’10 08/22/19 Open 5,276’5,286’4,492’4,501’10 08/22/19 Open T11 5,354’5,370’4,557’4,570 16 8/14/19 Open T12 5,520’5,545’4,692’4,713’30 03/15/19 Open 5,562’5,582’4,727’4,743’20 10/13/18 Isolated T17A 6,249’6,259’5,298’5,307’10 11/06/17 Isolated 6,259’6,265’5,307’5,312’6 12/14/17 Isolated 6,270’6,285’5,316’5,328’15 12/14/17 Isolated T18 6,418’6,433’5,440’5,452’15 02/07/18 Isolated T43 6,887’6,899’5,844’5,855’12 10/21/17 Isolated T142 8,767’8,777’7,677’7,687’10 10/13/17 Isolated T146 8,975’8,995’7,884’7,904’20 09/26/17 Isolated T147 9,022'9,033'7,931'7,942'11 07/27/17 Isolated 3 T142 5 2 Updated by CRR 08-31-21 SCHEMATIC Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ 1 16” 7-5/8” 4-1/2” No.Depth ID Item 1 1,280’3.958”Swell Packer 2 5,555’CIBP 03/16/19 3 6,881’3.375”Permanent Patch 6,881’-6,903’ 11/06/17 4 8,760’CIBP w/ 10’ of cement 10/21/17 5 8,950’CIBP w/ 26’ cement 10/12/17 6 9,012’CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875”Surf 1,418’ 4-1/2"Prod Csg 12.6 L-80 TXP 3.958”Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole: 84 BBL of 12 ppg Class A lead and 36 BBLs 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole: 240 BBL 12.5ppg Type I-II cement, followed with 32 BBL of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. 7/8/17 SCMT shows solid cement up to 1,430’ MD. ToC at 1,180’ MD RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 6 T146 T147 T43 4 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft Date Status Perfs per Sundry T2 4,501’4,517’3,843’3,856’16 07/30/20 Open T4 4,632’4,643’3,950’3,959’11 08/22/19 Open T5 4,654’4,661’3,968’3,974’7 07/30/20 Open T5B 4,793’4,799’4,085’4,090’6 07/30/20 Open T6A 4,984’4,994’4,246’4,254’10 07/30/30 Open T8 5,058’5,078’4,308’4,325’20 08/22/19 Open T10 5,259’5,269’4,478’4,486’10 08/22/19 Open 5,276’5,286’4,492’4,501’10 08/22/19 Open T11 5,354’5,370’4,557’4,570 16 8/14/19 Open T12 5,520’5,545’4,692’4,713’30 03/15/19 Open 5,562’5,582’4,727’4,743’20 10/13/18 Isolated T17A 6,249’6,259’5,298’5,307’10 11/06/17 Isolated 6,259’6,265’5,307’5,312’6 12/14/17 Isolated 6,270’6,285’5,316’5,328’15 12/14/17 Isolated T18 6,418’6,433’5,440’5,452’15 02/07/18 Isolated T43 6,887’6,899’5,844’5,855’12 10/21/17 Isolated T142 8,767’8,777’7,677’7,687’10 10/13/17 Isolated T146 8,975’8,995’7,884’7,904’20 09/26/17 Isolated T147 9,022'9,033'7,931'7,942'11 07/27/17 Isolated 3 T142 5 2 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. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company FALLS CREEK 3 501332052400 203102 12/17/2020 SET PLUG Yellowjacket FALLS CREEK 3 501332052400 203102 1/27/2021 SET PLUG/GPT Yellowjacket GREYSTONE 1 502312005000 216067 8/9/2020 SET PLUG Yellowjacket KALOTSA 2 50133206590000 216155 6/8/2021 PERF / GPT Yellowjacket KALOTSA 3 50133206610000 217028 7/30/2020 PERF / GPT Yellowjacket KALOTSA 7 50133206930000 220067 1/5/2021 PERF Yellowjacket Please include current contact information if different from above. Received By: 06/28/2021 37' (6HW By Abby Bell at 12:22 pm, Jun 28, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 5555; 8760; Total Depth measured 9,265 feet 8950; 9012 feet true vertical 8,173 feet N/A feet Effective Depth measured 5,555 feet 1,280 feet true vertical 4,721 feet 1,203 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A; N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr 1,280' MD 1,203' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 WINJ WAG 412 Water-Bbl MD 120' 1,418' 0 Oil-Bbl measured true vertical Packer 4-1/2"9,252'8,160' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ninilchik Field - Beluga/Tyonek Gas PoolN/A measured TVD Tubing Pressure 1670 Ninilchik Unit Kalotsa 3 N/A C061505 SHL / ADL359242 / ADL384372 TPH/BHL / FEE CIRI Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-028 50-133-20661-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-296 480 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 2 Casing Pressure Liner 1,851 0 Representative Daily Average Production or Injection Data 120' 1,418' 9,252' Conductor Surface Intermediate Production 7,500psi Casing Structural 16" 7-5/8" Length 6,890psi Collapse 1,410psi 4,790psi ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 2,980psi 8,430psi 120' 1,316' t e Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 11:50 am, Aug 14, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.14 10:55:06 -08'00' Taylor Wellman gls 9/28/20 Perforate DSR-8/17/2020 RBDMS HEW 8/14/2020 SFD 8/17/2020 Rig Start Date End Date E-Line 7/30/20 7/30/20 07/30/2020 - Thursday PTW and JSA. Spot equipment and rig up lubricator. PT lubricator to 250 psi low and 2,500 psi high. Well flowing 553 mcfd at 60.1 psi. RIH w/ 1-11/16' GPT and correlate to OHL. Didn't find solid fluid level but from 5,280' down to tag depth at 5,555' fall back or something going on. Ran a correlation log and send to town to see if we are on depth. Town sent back an las log to tie into. On depth. Lost DC power on panel. Trouble shot and fix problem. RIH w/Gun #1, 2-7/8" x 10' HC Razor, 6 spf, 60 deg phase and tie into OHL las. Run correlation log and send to town. Get ok to perforate from 4,984' to 4,994' w/well flowing 553 mcfd at 60.1 psi. Spot and fire gun. After 5 min - 552 mcfd at 60.1 psi, 10 min - 554 mcfd. at 60.0 psi and 15 min - 555.2 mcfd at 59.9 psi. POOH. all shots fired and gun was dry. RIH w/Gun #2, 2-7/8" x 6' HC Razor, 6 spf, 60 deg phase and tie into OHL las. Run correlation log and send to town. Get ok to perforate from 4,793' to 4,799' w/well flowing 547.7 mcfd at 60.4 psi. Spot and fire gun. After 5 min - 574.9 mcfd at 60.2 psi, 10 min - 572.9 mcfd. at 60.2 psi and 15 min - 575.7 mcfd at 60.2 psi. POOH. All shots fired and gun was dry. RIH w/Gun #3, 2-7/8" x 7' HC Razor, 6 spf, 60 deg phase and tie into OHL las. Run correlation log and send to town. Get ok to perf from 4,654' to 4,661' w/well flowing 581 mcfd at 60.2 psi. Spotted and fired gun and scada went down. POOH and all shots fired and gun was dry. RIH w/Gun #4, 2-7/8" x 16' HC Razor, 6 spf, 60 deg phase and tie into OHL las. Run correlation log and send to town. Get ok to perforate from 4,501' to 4,517' w/well flowing 801 mcfd w/wellhead pressure pinched back to 125 psi. Pad Op pinched back well head pressure while spotting gun. Spotted and fired gun with well flowing and lost 100 lb line tension. They had 400 lb of tool wt. Started gaining pressure but scada went on me and when it came back on we were gaining pressure and rate. POOH all shots fired and gun was dry. Rig down equipment and turn well over to field. Well flowing 1.7 million at 455 psi. Daily Operations: Hilcorp Alaska, LLC. Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 3 50-133-20661-00-00 217-028 Updated by DMA 08-06-20 SCHEMATIC Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ TOC @ 9,007’ 09/10/17 TOC @ 8,750’ 10/21/17 TOC @ 8,924’ 10/12/17 1 16” 7-5/8” 6-3/4” Hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,280’ 3.958” 6.875” Swell Packer 2 5,555’ CIBP 03/16/19 3 6,881’ 3.375” Permanent Patch 6,881’-6,903’ 11/06/17 4 8,760’ 3.958” CIBP w/ 10’ of cement 10/21/17 5 8,950’ 3.958” CIBP w/ 26’ cement 10/12/17 6 9,012’ 3.958” CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875” Surf 1,418’ 4-1/2" Prod Csg 12.6 L-80 TXP 3.958” Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8” hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole. 240 BBL (675 sx) 12.5 Type I-II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 6 T146 T147 T43 4 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T2 4,501’ 4,517’ 3,843’ 3,856’ 16 07/30/20 Open T4 4,632’ 4,643’ 3,950’ 3,959’ 11 08/22/19 Open T5 4,654’ 4,661’ 3,968’ 3,974’ 7 07/30/20 Open T5B 4,793’ 4,799’ 4,085’ 4,090’ 6 07/30/20 Open T6A 4,984’ 4,994’ 4,246’ 4,254’ 10 07/30/30 Open T8 5,058’ 5,078’ 4,308’ 4,325’ 20 08/22/19 Open T10 5,259’ 5,269’ 4,478’ 4,486’ 10 08/22/19 Open 5,276’ 5,286’ 4,492’ 4,501’ 10 08/22/19 Open T11 5,354’ 5,370’ 4,557’ 4,570 16 8/14/19 Open T12 5,520’ 5,545’ 4,692’ 4,713’ 30 03/15/19 Open 5,562’ 5,582’ 4,727’ 4,743’ 20 10/13/18 Isolated T17A 6,249’ 6,259’ 5,298’ 5,307’ 10 11/06/17 Isolated 6,259’ 6,265’ 5,307’ 5,312’ 6 12/14/17 Isolated 6,270’ 6,285’ 5,316’ 5,328’ 15 12/14/17 Isolated T18 6,418’ 6,433’ 5,440’ 5,452’ 15 02/07/18 Isolated T43 6,887’ 6,899’ 5,844’ 5,855’ 12 10/21/17 Isolated T142 8,767’ 8,777’ 7,677’ 7,687’ 10 10/13/17 Isolated T146 8,975’ 8,995’ 7,884’ 7,904’ 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T17A T18 3 3.80" (3.375" ID) X 21' Owens Tubing Patch F/6,881’ – 6,903’. T142 5 2 T12 T6A T2 T5B T8 T10 T11 T12 T2 T4 T5 T5B T6A T4 T5B T5B 4,793’4,799’4,085’4,090’6 07/30/20 Open T2 4,501’4,517’3,843’3,856’16 07/30/20 Open T5 4,654’4,661’3,968’3,974’7 07/30/20 Open T6A 4,984’4,994’4,246’4,254’10 07/30/30 Open 20 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 NINILCHIK UNIT KALOTSA 3 9. Property Designation (Lease Number):10. Field/Pool(s): Ninilchik Field - Beluga/Tyonek Gas pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD): 5555'; Junk (MD): 9,265'n/a Casing Collapse Structural Conductor 1410 psi Surface 4790 psi Intermediate Production 7500 psi 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: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 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 25, 2020 n/a 9,252' Perforation Depth MD (ft): See Attached Schematic 9,252'8,160'4-1/2" 16" 7-5/8" 120' 1,418' 2980 psi 6890 psi 120' 1,316' 120' 1,418' n/a TVD Burst n/a 8430 psi MDLengthSize CO701C 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 C061505 SHL / ADL359242 / ADL384372 TPH/BHL / FEE CIRI 217-028 50-133-20661-00-00 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic ryan.rupert@hilcorp.com 8,173'5,555'4121'~1490 psi 8760'; 8950'; 9012' Baker swell Packer, n/a 1280' MD / 1203' TVD; NA Perforation Depth TVD (ft):Tubing Size: m n P 2 6 5 6 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:05 pm, Jul 14, 2020 320-296 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.07.14 12:39:18 -08'00' Taylor Wellman DSR-7/14/2020DLB 07/14/2020 X X 10-404 VTL 7/21/20Comm. 7/22/2020 dts 7/22/2020 JLC 7/22/2020 RBDMS HEW 7/24/2020 Well: Kalotsa #3 Date: 7/10/2020 Well Name: Kalotsa #3 API Number: 50-133-20661-00-00 Current Status: Online Gas Producer Leg: N/A Estimated Start Date: 7/25/20 Rig: E-line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Ryan Rupert (907) 777-8503 (O) (907) 301-1736 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Maximum Expected BHP: ~ 1,932 psi @ 4,421’ TVD (Based on normal pressure gradient) Max. Potential Surface Pressure: ~ 1,490 psi (Gas gradient to surface (0.10psi/ft)) Brief Well Summary Kalotsa #3 is currently producing at ~450 mcf and no water, and has been a stable online producer since the current sets of perfs were added 8/23/19. Given the expected decline, and more pay uphole, the below additional perfs are being pursued. A CBL ran July 8, 2017 shows good cement covering all of the Sands in his Sundry Application. The purpose of this sundry/work is to add the below sands to this online well. Notes regarding Wellbore Condition - Min ID: 3.958” (tubing) - Max inclination: All <40 degrees - Max DLS: all < 6 degrees / 100’ - Last drifts: o Tag- 5552’ MD (8/22/19) with an EL GPT (plug tag) o 5078’ MD (8/22/20) with an EL perf gun (2-7/8” x 20’) Safety Concerns x Nitrogen Operations o Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. o Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) o Ensure all crews are aware of stop job authority Well: Kalotsa #3 Date: 7/10/2020 E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low / 2,500 psi high 2. RIH W/ GPT tool and find fluid level. If fluid level is over the depth to shoot the new perfs, then talk to the Operations Engineer about using Nitrogen. 3. If needed, RU Nitrogen Truck and pressure up on well per OE and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 4. Rig up perf guns and RIH 5. Perforate the sands listed in the table below. Zone Sand Top (MD) Bottom (MD) Total Footage (MD) Top (TVD) Bottom (TVD) Beluga BEL_120 ±3,969' ±4,031' 62' ±3,414' ±3,464' Tyonek T-2 ±4,500' ±4,525' 25' ±3,842' ±3,862' Tyonek T-5 ±4,653' ±4,663' 10' ±3,967' ±3,976' Tyonek T-5B ±4,788' ±4,801' 13' ±4,081' ±4,091' Tyonek T-6A ±4,980' ±4,996' 16' ±4,243' ±4,256' Tyonek T-9A ±5,180' ±5,192' 12' ±4,411' ±4,421' a. Based on conditions, we may shoot the intervals with the well flowing. Or may increase tubing pressure up to 1100 psi prior to shooting. 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480’ in the Paxton #5 well and 9,600’ in the Paxton #1 well. f. Record 5, 10, and 15 minute tubing pressures after firing 6. POOH, RD e-line. 7. Turn well over to production. E-line Procedure (Contingency): 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 3. RIH and set 4-1/2” Liner Patch or set CIBP above the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure – N2 Operations Updated by CRR 7-10-20 SCHEMATIC Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ TOC @ 9,007’ 09/10/17 TOC @ 8,750’ 10/21/17 TOC @ 8,924’ 10/12/17 1 16” 7-5/8” 6-3/4” Hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,280’ 3.958” 6.875” Swell Packer 2 5,555’ CIBP 03/16/19 3 6,881’ 3.375” Permanent Patch 6,881’-6,903’ 11/06/17 4 8,760’ 3.958” CIBP w/ 10’ of cement 10/21/17 5 8,950’ 3.958” CIBP w/ 26’ cement 10/12/17 6 9,012’ 3.958” CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875” Surf 1,418’ 4-1/2" Prod Csg 12.6 L-80 TXP 3.958” Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8” hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole. 240 BBL (675 sx) 12.5 Type I-II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 6 T146 T147 T43 4 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T4 4,632’ 4,643’ 3,950’ 3,959’ 11 08/22/19 Open T8 5,058’ 5,078’ 4,308’ 4,325’ 20 08/22/19 Open T10 5,259’ 5,269’ 4,478’ 4,486’ 10 08/22/19 Open 5,276’ 5,286’ 4,492’ 4,501’ 10 08/22/19 Open T11 5,354’ 5,370’ 4,557’ 4,570 16 8/14/19 Open T12 5,520’ 5,545’ 4,692’ 4,713’ 30 03/15/19 Open 5,562’ 5,582’ 4,727’ 4,743’ 20 10/13/18 Isolated T17A 6,249’ 6,259’ 5,298’ 5,307’ 10 11/06/17 Isolated 6,259’ 6,265’ 5,307’ 5,312’ 6 12/14/17 Isolated 6,270’ 6,285’ 5,316’ 5,328’ 15 12/14/17 Isolated T18 6,418’ 6,433’ 5,440’ 5,452’ 15 02/07/18 Isolated T43 6,887’ 6,899’ 5,844’ 5,855’ 12 10/21/17 Isolated T142 8,767’ 8,777’ 7,677’ 7,687’ 10 10/13/17 Isolated T146 8,975’ 8,995’ 7,884’ 7,904’ 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T17A T18 3 3.80" (3.375" ID) X 21' Owens Tubing Patch F/6,881’ – 6,903’. T142 5 2 T12 T12 T4 T8 T10 T11 Updated by CRR 7-10-20 Proposed SCHEMATIC Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 PBTD = 5,555’ / PBTVD = 4,721’ TD = 9,265’ / TVD = 8,173’ RKB to GL = 19.1’ TOC @ 9,007’ 09/10/17 TOC @ 8,750’ 10/21/17 TOC @ 8,924’ 10/12/17 1 16” 7-5/8” 6-3/4” Hole 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,280’ 3.958” 6.875” Swell Packer 2 5,555’ CIBP 03/16/19 3 6,881’ 3.375” Permanent Patch 6,881’-6,903’ 11/06/17 4 8,760’ 3.958” CIBP w/ 10’ of cement 10/21/17 5 8,950’ 3.958” CIBP w/ 26’ cement 10/12/17 6 9,012’ 3.958” CIBP w/ 5’ of cement 9/10/17 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 BTC 6.875” Surf 1,418’ 4-1/2" Prod Csg 12.6 L-80 TXP 3.958” Surf 9,252’ OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8” hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2” 6-3/4” hole. 240 BBL (675 sx) 12.5 Type I-II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. RA @ 3,987’ RA @ 5,438’ RA @ 6,474’ RA @ 7,470’ 6 T146 T147 T43 4 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL_120 ±3696 ±4031 ±3414 ±3464 62 TBD Proposed T2 ±4500 ±4525 ±3842 ±3862 25 TBD Proposed T4 4,632’ 4,643’ 3,950’ 3,959’ 11 08/22/19 Open T5 ±4653 ±4663 ±3967 ±3976 10 TBD Proposed T5B ±4788 ±4801 ±4081 ±4091 13 TBD Proposed T6A ±4980 ±4996 ±4243 ±4256 16 TBD Proposed T8 5,058’ 5,078’ 4,308’ 4,325’ 20 08/22/19 Open T9A ±5180 ±5192 ±4411 ±4421 12 TBD Proposed T10 5,259’ 5,269’ 4,478’ 4,486’ 10 08/22/19 Open 5,276’ 5,286’ 4,492’ 4,501’ 10 08/22/19 Open T11 5,354’ 5,370’ 4,557’ 4,570 16 8/14/19 Open T12 5,520’ 5,545’ 4,692’ 4,713’ 30 03/15/19 Open 5,562’ 5,582’ 4,727’ 4,743’ 20 10/13/18 Isolated T17A 6,249’ 6,259’ 5,298’ 5,307’ 10 11/06/17 Isolated 6,259’ 6,265’ 5,307’ 5,312’ 6 12/14/17 Isolated 6,270’ 6,285’ 5,316’ 5,328’ 15 12/14/17 Isolated T18 6,418’ 6,433’ 5,440’ 5,452’ 15 02/07/18 Isolated T43 6,887’ 6,899’ 5,844’ 5,855’ 12 10/21/17 Isolated T142 8,767’ 8,777’ 7,677’ 7,687’ 10 10/13/17 Isolated T146 8,975’ 8,995’ 7,884’ 7,904’ 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T17A T18 3 3.80" (3.375" ID) X 21' Owens Tubing Patch F/6,881’ – 6,903’. T142 5 2 T12 T8 T9A T10 T11 T-12 BEL_120 T2 T4 T5 T5B T6A STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate Li Pull Tubing LJ Operations shutdown Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: N2 Displace ❑✓ 2. Operator 4. Well Class Before Work: Name: Hilcorp Alaska, LLC 5. Permit to Drill Number: Development Q Exploratory ❑ 217-028 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-133-20661-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: C061505 SHL / ADL359242 / ADL384372 TPH/BHL / FEE CIRI Kalotsa 3 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik Field - Beluga/Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,265 feet Plugs measured 5555; 6,239; 9,007 feet true vertical 8,173 feet Junk measured N/A feet Effective Depth measured 5,555 feet Packer measured 1,280 feet true vertical 4,721 feet true vertical 1,203 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A; N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker Swell Pkr 1,280' MD 1,203' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data OH -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 17 1185 Subsequent to operation: 0 948 0 6 785 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory[] Development p ❑ Service[:] Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-338 & 319-375 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(oihilcoro com Authorized Signature:,- Date: U p Lf 1-.,, Contact Phone: 777-8420 Form 10-404 Revised 4/2017 J' tf/ //.7 X is -11 15' RBDMS.L`61 OCT 0 9 2019 Submit Original Only Hilcorp Alaska, LLC, Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E -Line 50-133-20661-00 1 217-028 8/14/19 10/1/19 Daily Operations: 08/14/2019- Wednesday Sign in. Mobe to location. PTW and JSA. Spot and rig up equipment. PT lub to 250 psi low and 3,000 psi high. TP - 1,187 psi. RIH w/GPT tool and tie into OHL. Tag plug at 5,555' and find FL at,5534'. Run correlation log and send to town. POOH. RIH w/ 2-7/8" x 16' Razar HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Get ok to perffrom 5,354' to 5,370' with 1,168.7 psi on tubing. Spotted and fired gun at 1247 hrs. After 5 min - 1,170.1 psi, 10 min - 1,170 psi and 15 min - 1,169.3 psi. POOH. All shots fired and gun was dry. Rig down lubricator and equipment. Turn well over to field. 08/22/2019 - Thursday PTW and JSA. Spot and rig up equipment. PT lubricator 250 psi low and 3,500 psi high. TP - 1,050 psi. RIH w/GPT tool, tie into OHL. and tag at 5,552'. Found fluid level at 5,444'. Ran correlation log and send to town. POOH. RIH w/ 2-7/8" x 10' Razar HC, 6 spf, 60 deg phase and tie into GPT log. Run Perf correlation log #1 and send to town. Get ok to pert from 5,276" to 5,286' with 1,057 psi on tubing. Spotted and fired gun at 1143 hrs. After 5 min - 1,060 psi, 10 min - 1,060 psi and 15 min - 1,060 psi. POOH. All shots fired and gun was dry. RIH w/ 2-7/8" x 10' Razar HC, 6 spf, 60 deg phase and tie into GPT log. Ran log #2 but Didn't have to send log to town. Used perf log #1 to correlated with. Spotted and fired gun from 5,259' to 5,269' with 1,057 psi on tubing (1318 hrs). After 5 min - 1,061 psi, 10 min - 1,061 psi, and 15 min - 1,060 psi. POOH. All shots fired and gun was dry. RIH w/ 2-7/8" x 20' Razar HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log #3 and send to town. Get ok to perf from 5,058' to 5,078' with 1,066 psi on tubing. Spotted and fired gun at 1512 hrs. After 5 min - 1,071 psi, 10 min - 1,070 psi and 15 min - 1,070 psi. POOH. All shots fired and gun was dry. RIH w/ 2-7/8" x 11' Razar HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log #4 and send to town. Get ok to perf from 4,632' to 4,643' with 1,080 psi on tubing. Spotted and fired gun at 1512 hrs. After 5 min - 1,114 psi, 10 min - 1,138 psi and 15 min - 1,164 psi. POOH. All shots fired and gun was dry. Rig down lubricator off well. Turn well over to field and rig down rest of equipment. 10/01/2019 -Tuesday Met with the Reservoir Engineer concerning perforating the remaining sands on this Sundry. Decision was made to postpone the remaining perforating until more compression could be added to the field. We will close Sundry and re -sundry the remaining sands at that time. 16" Ninilchik Unit SCHEMATIC Kalotsa #3 11 PTD: 217-028 Hileuey Alucku, LLC API: 50-133-20661-00 RKB to GL= 19.1' 7-5/8„ i RA @ 3,987' Wa 6 -3/4 - Hole RA @ 5,438' .' RA @ 7,470' o° TOC @ 8,750 10/21/17 TOC @ 8,924 TOC @ 9,007' 09/10/17 - - 4-1/2" - Q..IN '..� PBTD = 5,555'/ PBTVD = 4,721' TD = 9,265'/ TVD = 8,173' ori T4 (7 TS 7 T10 \\ T12 2 T12 T17A CACING DFTAII Size Type Wt Grade Conn.:11 Item 1 Btm 16" Conductor -Driven tSetDepth7-5/8" 84 X-56 Weld 5,555' 4,643' 120' 3 Surf Csg 29.7 L-80 BTC Permanent Patch 6,881'-6,903'11/06/17 4 1,418' 4-1/2" Prod Csg 12.6 L-80 UP 8,950' 3.958" 9,252' IFWF1 PV DFTAII No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 5,555' 4,643' CIBP 03/16/19 3 6,881' 3.375" 08/22/19 Permanent Patch 6,881'-6,903'11/06/17 4 8,760' 3.958" CIBP w/ 10' of cement 10/21/17 5 8,950' 3.958" CIBP w/26' cement 10/12/17 6 9,012' 3.958" CIBP w/ 5' of cement 9/10/17 PERFORATION DFTAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T4 4,632' 4,643' 3,950' 3,959' 11 08/22/19 Open T8 5,058' 5,078' 4,308' 4,325' 20 08/22/19 Open T10 5,259' 5,269' 4,478' 4,486' 30 08/22/19 Open 5,276' 5,286' 4,492' 4,501' 10 08/22/19 Open T12 5,527 51545' 4,692' 4,713' 30 03/15/19 Open 5,562' 5,582' 4,727' 4,743' 20 10/13/18 Isolated 6,249' 6,259' 5,298' 5,307' 30 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 6 12/14/17 Isolated 6,270' 6,285' 5,316' 5,328' 15 12/14/17 Isolated T18 6,418' 6,433' 5,447 5,452' 15 02/07/18 Isolated T43 6,887 6,899' 5,844' 5,855' 12 10/21/17 Isolated T142 8,767' 8,777' 7,677' 7,687' 10 10/13/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T18 T43 3.80" (3.375" ID) X 21' Owens Tubing Patch 3 F/6,881' - 6,903'. T142 4 5 T146 6 T147 OPEN HOLE/ CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 Ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112 6 -3/4" hole. 240 BBL (675 sx) 12.5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by DMA 10-03-19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninlichik Field, Beluga/Tyonek Gas Pool, Kalotsa 3 Permit to Drill Number: 217-028 Sundry Number: 319-375 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �.aogcc.a lasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner c DATED this - day of August, 2019. IDDMSI'AUG 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AAc 2e 2Rn AUG 14 2019 1. Type of Request: Abandon ❑ Plug Perforations[] Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N2 Displace ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 • Stratigraphic ❑ Service ❑ 217-028 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20661-00-00 ' 7. If perforating: S. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701C Will planned Perforations require a spacing exception? Yes ❑ No El Ninilchik Unit Kalotsa 3 9. Property Designation (Lease Number):10. Field/Pool(s): C061505 SHL / ADL359242/ ADL384372 TPH/BHL / FEE CIRI Ninilchik Field - Beluga/Tyonek Gas Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 5,555; Junk (MD): 9,265' 8,173' 5,555' 4,721' -1520 8,760; 8,950; 9,012 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,415' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Pkr; N/A 1,280' MD/1,203' TVD; N/A 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: August 30, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑� • WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: CtWO OOd hilcor .Cor11 Contact Phone: 777-8443 \ Authorized Signature. Date: � A 1-0\`\ COMMISSION WE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ I A3 -7I � -f✓. UI1 Plug Integrity ❑ BOP Test E] Mechanical Integrity Test ❑ Location Clearance ❑ Other: ■ryA, C Post Initial Injection MIT Req'd? Yes [:]No ❑ RBDMSI�''pUG 19 2019 Ll Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY�/' 5/) Approved by: COMMISSIONER THE COMMISSION ` T Date: / " 1 I l I 1 Form 10.4 evised 4/ 17 Iv �/q o n+ n 1 N A t proved application is v li f'bl(`I rd`prJ1t to of approval. -' �/� Submit Form and Attachments in Duplicate AP. If //�j', 16" Ninilchik Unit KaloSCHEMATIC PTD: a 2177-- 11 PTD: 028 API: 50-133-20661-00 HiMvxp Alceka, W.0 RKB to GL = 19.1' ../_5/5,. RA @ 3,987' 6 -3/4 - Hole "• r RA@5,438' ,` �• a RA @ 6,474''{" i+ RA @ 7,470' Toc @ 8175V 30/2/17 - Y.� TOC @8,924 10/12/1 TOC @ 9,007' 09/10/17 - - PBTD = 5,555'/ PBTVD = 4,721' TD = 9,265'/ TVD = 8,173' 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 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 5,555' 5,545' CIBP 03/16/19 3 6,881' 3.375" 03/15/19 Permanent Patch 6,881'-6,903' 11/06/17 4 8,760' 3.958" CIBP w/ 10' of cement 10/21/17 5 8,950' 3.958" CIBP w/ 26' cement 10/12/17 6 9,012' 3.958" CIBP w/ 5' of cement 9/10/17 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T12 51520' 5,545' 4,692' 4,713' 30 03/15/19 Open T12 5,562' 5,582' 4,727' 4,743' 20 10/13/18 Isolated 6,249' 6,259' 5,298' 5,307' 10 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 6 12/14/17 Isolated 6,270' 6,285' 5,316' 5,328' 15 12/14/17 Isolated T18 6,418' 6,433' 5,440' 5,452' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T142 8,767' 8,777' 7,677' 7,687' 30 10/13/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 1 7,931' 1 7,942' 1 11 1 07/27/17 1 Isolated T12 7 l` T12 IT17A T18 T43 3.80" (3.375" ID) X 21' Owens Tubing Patch F/6,881'-6,903'. T142 4 5 T146 6 T147 OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112" 6-3/4" hole. 240 BBL (675 sx)12,5 Type I-II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by DMA 06-27-19 RKB to GL= 19.1' 7-5/8" Toc @ Type ±4,600' Grade RA @ 3,987' Top 6 -3/4 - 16" Conductor - Driven to Set Depth Hole 16 d • RA@5,438' < �• w �t RA @ 6,474' a. L-80 BTC 6.875" RA @ 7,470' 1,418 j9,1252" C A Prod Csg n L-80 TXP 3.958" TOC @ 8,750' I 10/21/17 9,012' roc l/2„ AL . r PBTD = 5,555'/ PBTVD = 4,721' TD = 9,265'/ TVD = 8,173' PROPOSED SCHEMATIC CASING DETAIL Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 Size Type Wt Grade Conn. ID Top Btm 16" Conductor - Driven to Set Depth 84 X-56 Weld 15.01" Surf 20' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,418 j9,1252" 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf CIBP w/ 26'cement 10/12/17 JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 3A ±4,620' ±3,673' CIBP w/ 20' cement 2 5,555' Proposed CIBP 03/16/19 3 6,881' 3.375" ±3,821' Permanent Patch 6,881'-6,903'11/06/17 4 8,760' 3.958" CIBP w/ 10' of cement 10/21/17 5 8,950' 3.958" CIBP w/ 26'cement 10/12/17 6 9,012' 3.958" CIBP w/ 5' of cement 9/10/17 PERFORATION DETAII. BEL 98 BEL106 IA T3 T4 TO T10 T11 T12 2 T12 Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL 98 ±3,656' ±3,673' ±3,156' ±3,170' ±17 Proposed TBD BEL 106 ±3,809' ±3,821' ±3,283' ±3,293' ±12 Proposed TBD T3 ±4,498' ±4,540' ±3,840' ±3874• ±42 Proposed TBD T4 ±4,630' ±4,641' ±3,948' ±3,957' ±11 Proposed TBD TO ±5,058' ±5,105' ±4,308' ±4,348' ±47 Proposed TBD TSO ±5,257' ±5,290' ±4,475' ±4,503' ±33 Proposed TBD T11 ±5,354' ±5,370' ±4,557' ±4,570' ±16 Proposed TBD T12 5,520' 5,545' 4,692' 4,713' 30 03/15/19 Open T12 5,562' 5,582' 4,727' 4,743' 20 10/13/18 Isolated 6,249' 6,259' 5,298' 5,307' 10 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 6 12/14/17 Isolated 6,270' 6,285' 5,316' 5,328' 15 12/14/17 Isolated T18 6,418' 6,433' 5,440' 5,452' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T142 T346 8,767' 8,975' 8,777' 8,995' 7,677' 7,884' 7,687' 7,904' 30 20 10/13/17 09{26/17 Isolated Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T142 4 5 T146 6 T147 OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 881-s (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/1" T17A Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. T18 _ T43 3.80" (3.375" ID) X 21' Owens Tubing Patch 3 F/6,881'-6,903'. T142 4 5 T146 6 T147 OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 881-s (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/1" 6-3/4" hole. 240 BBL (675 sx) 12.5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by CMT 08-13-19 H Ililm" Alaska, LG Well Prognosis Well: Kalotsa #3 Date: 8/13/2019 Well Name: Kalotsa #3 API Number: 50-133-20661-00-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: Aug 30, 2019 Rig: E -line Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) AFE Number: Maximum Expected BHP: — 1,971 psi @ 4,503' TVD (Based on normal gradient of 0.437 psi/ft and the lowest perforation) Max. Potential Surface Pressure: — 1,520 psi @ 4,503' TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary The Lower T-12 was perforated in the Kalotsa #3 in October 2018. Initial production was 6 MMscfd but water gradually came in over the next 3 months and the well loaded up and died. -� The Upper T-12 perforations were added in March 2019. No appreciable pressure or rate changes were observed. The proposed perforations in T11, T81 T4, BEL 106 and BEL 98 sands and the CIBP above the Tyonek sands are included in Approved Sundry 319-338. These items have been indicated throughout in purple. Notes Regarding Wellbore Condition • A CBL ran July 8, 2017 shows excellent cement covering all of the Sands in this Sundry Application. Safet Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. (• )Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) • Ensure all crews are aware of stop job authority E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 3,000 psi Hi 250 psi Low. 2. RIH W/ GPT tool and find fluid level. If fluid level is over the depth to shoot the new perfs, then talk to the Operations Engineer about using Nitrogen and setting a plug. 3. RU Nitrogen Truck. 4. If needed, pressure up on well and push water back into formation. Use GPT tool to confirm Water level is below interval to pert. 5. Pressure up well to 1,575 psi. 6. Perforate the sands listed in the table one at a time and test after shooting each interval with 2- 7/8" 6 SPF 60 deg phased pert guns (up to 12 SPF with 2 perf runs). N Ifil." Alaska, LG Well Prognosis Well: Kalotsa #3 Date:8/13/2019 7. Discuss test results after each perforation with the Operations Engineer before progressing to the next interval. Note: If the Tyonek intervals are not producing or a decision is made to progress to the Beluga Sands, a plug will need to be set above the Tyonek perfs with 20ft of cement on top of it prior to shooting the Beluga Sand intervals. 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 8. POOH. 9. RD a -line. 10. Turn well over to production. (Test SSV with -in 5 days of stable production on well- notify AOGCC 24hrs before testing) E -line Procedure (Contingency): 1. If these zones produce sand and/or water and need to be isolated. 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 psi Low. 3. RIH and set 4-1/2" Casing Patch or set CIBP above the zone and dump 20' of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure - N2 Operations Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Tyonek TIO ±5,257' +5,290' ±4,475' ±4,503' 33' / Tyonek T3 ±4,498 ±4,540' ±3,840' ±3,874' 42' 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 8. POOH. 9. RD a -line. 10. Turn well over to production. (Test SSV with -in 5 days of stable production on well- notify AOGCC 24hrs before testing) E -line Procedure (Contingency): 1. If these zones produce sand and/or water and need to be isolated. 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 psi Low. 3. RIH and set 4-1/2" Casing Patch or set CIBP above the zone and dump 20' of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure - N2 Operations 0 STANDARD WELL PROCEDURE HilrorpAlaska, LLC NITROGEN OPERATIONS 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/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 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. 12/08/2015 FINALvl Page 1 of 1 THE STATE OIALASKA GOVERNOR MIKE, DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Ninlichik Unit Kalotsa 3 Permit to Drill Number: 217-028 Sundry Number: 319-338 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aog cc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ?I;,ieI.)`ChmieZIoPw6ski Commissioner DATED this 3D day of July, 2019. RBDMS�JUL 3 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Suspend ❑ Perforate Q • Other Stimulate p Pull Tubing ❑ ' Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ . Operator Name: 4. Current Well Class: 5 F Hilcorp Alaska, LLC Exploratory ❑ Development Q t. Address: 3800 Centerpoint Dr, Suite 1400 Strafigraphic ❑ Service ❑ 6. A Anchorage Alaska 99503 What Regulation or Conservation Order governs well spacing in this pool? CO 701C Will planned perforations renuire a snaninn >—ri—i __ n {0 Ds5 7��jr�� Operations shutdown ❑ Change Approved Program n Other: 1 Drill Number: 217-028 Iber: 50-133-20661-00-00 Ninilchik I Wt K.Wn u 9. Property Designation (Lease Number): _10. Field/Pool(s): C061505 SHE/ ADL359242 / ADL384372 TPH/BHL / FEE CIRI JrNinilchik Field - Beluga/Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): 5,555; Junk (MD): 9,265' • 8,173' • 5,555' 4,721'-1,543 psi 8,760; 8,950; 9,012 N/A CastLength Size MD ND Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4.1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Baker Swell Pkr; N/A 1,280' MD/1,203' ND; N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strafigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 30, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended El16. Approval: Date: GAS Q • WAG ❑ GSTOR ❑ SPLUG 11CommVissiiso on Representative: ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not GINJ E] Op Shutdown Abandoned El be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted KramerAuthorized Title: Operations Manager �7 Contact Email: tkramer(�hilcom com Date: 1 TT , Z,J �� Contact Phone: 777-8420 Authorized Signatur : „� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3oq-3 S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMSIL�('�itq 312019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: yD U APPROVED BY Approved by:I�e COMMISSIONER THE COMMISSION Date: 21311c, Form 10- 03 Revised 4/2017 droved lJ_f�.� V I I V H L Approved a Placation Is vati or 12 months from the date of approval. Submit Form and Atlachmentsin Duplicate /JLxC -7-/f. .//' H Hil mm Al"6. LG Well Prognosis Well: Kalotsa #3 Date: 7/15/2019 Well Name: Kalotsa #3 API Number: 50-133-20661-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: July 30, 2019 Rig: E -line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (C) AFE Number: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary 2,000 psi @ 4,570' TVD 1,543 psi @ 4,570' TVD (Based on normal gradient of 0.437 psi/ft and the lowest perforation) (Based on expected BHP and gas gradient to surface (0.10psi/ft) The lower T-12 was perforated in the Kalotsa #3in October 2018. Initial production was 6 MMscfd but water gradually came in over the next 3 months and the well loaded up and died. The UpperT-12 perforations were added in March 2019. observed. Notes Regarding Wellbore Condition No appreciable pressure or rate changes were • A CBL ran July 8, 2017 shows excellent cement covering the all of the Sands in this Sundry Application. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people ✓ could enter. • Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) • Ensure all crews are aware of stop job authority E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 3,000 psi Hi 250 Low. 2. RIH W/ GPT tool and find fluid level. If fluid level is over the depth to shoot the new perfs, then talk the Operations Engineer about using Nitrogen and setting a plug. 3. If needed, RU Nitrogen Truck. Pressure un on well and Push water back into formation. Use GPT tool to confirm Water level is below interval to perf. S" 4. Pressure up well to 1,600 psi. 5. Perforate the sands listed in the table one at a t4' and test after shooting each interval with 2- 7/8" 6 SPF 60 deg phased perfguns (up to 12 SPF with 2 perf runs) Note: A plug will need to be set above the Tyonek perfs with 20ft of cement on top of it prior to 'v✓��/ shooting the Beluga Sand intervals. 701 c U !filen... ANA.. U, Well Prognosis Well: Kalotsa #3 Date 7/15/2019 Zone SandUTOP(MD)Btm(f)m(MD) Top(TVD) Btm(TVD) AmtTyonek T115,370' +4,557' +4,570' 16'Tyonek T85,105' +4,308' +4,348' 47'Tyonek T4,641' ±3,948' ±3,957' 11'Beluga BEL 103 g21' ±3283' ±3 293' 12'Beluga BEL 98,673'±3,170' 17' 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 6. POOH. 7. RD a -line. 8. Turn well over to production. (Test SSV with -in 5 days of stable production on well — notify AOGCC 24hrs before testing) E -line Procedure (Contingency)' 1. If these zones produce sand and/or water and needs to be isolated. 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 3. RIH and set 4-1/2" Casing Patch or plug across the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure— N2 Operations Ninilchik Unit SCHEMATIC Kalotsa #3 PTD: 217-028 Nikorp Alaska, l4A: API: 50-133-20661-00 RKB to GL=19.1' RA @ 3,987' C .♦ 6-3/4" Hole �} RA @ 5,438' �4 RA Cs] 6,474' RA @ 7,470' a TOC @ 8, 10/21/17 TOG @ 9,007" 09/10/17 - -'- --- T12 T12 C'AglNG nFTAII size Type Wt m GradeMBTC6.8751, Btm (TVD) Top Btm 16" Conductor - Driven to Set Depth 84 X-56 5,545' Surf 120' 7-5/8" Surf Csg 29.7 L-80Surf1,418' T12 760'3.958" 4-1/2" Prod Csg 12.6 L-80Surf 10/13/18 9,252' IFWFI RV nFTAII PFRMIPATInAl hFTAII Sands ID OD Item,280' Btm (TVD) 3.958" 6.875" Swell Packer T12 ,555' 5,545' CIBP 03/16/19 nNo.Depth 881' 3375" 03/15/19 Permanent Patch 6,881'-6,903' 11/06/17 T12 760'3.958" 5,582' CIBP w/ 30' of cement 10/21/17 4,743' 950'.m.nt 10/13/18 l0/12/17 012' 3.958" CIBP w/ 5' of cement 9/10/17 PFRMIPATInAl hFTAII Sands Top (MD) Btm (M D) Top (TVD) Btm (TVD) I Ft Date Status T12 5,520' 5,545' 4,692' 4,713' 30 03/15/19 Open T12 5,562' 5,582' 4,727' 4,743' 20 10/13/18 Isolated 6,249' 6,259' 5,298' 5,307' 30 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 6 12/14/17 Isolated 6,270' 6,285' 5,316' 5,328' 15 12/14/17 Isolated T18 6,418' 6,433' 5,440' 5,452' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated 7142 8,767' 8,777' 7,677' 7,687' 10 10/13/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 1 7,942' 1 11 07/27/17 1 Isolated T18 T43 3.80" (3.375" ID) X 21' Owens Tubing Patch 3 F/6,881'- 6,903'. T142 4 5 T146 6 .y� -+y- T147 41/2„ Id. ,® sig PBTD = 5,555'/ PBTVD = 4,721' TD = 9,265'/ TVD = 8,173' OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112' 6-3/4" hole. 240 BBL (675 sx) 12.5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbis during job, 3 bbls of spacer returned to surface. Updated by DMA 06-27-19 16" Ninilchik Unit PROPOSED SCHEMATIC PTDt217-028 B„1Lc API: 50-133-20661-00 RKB to GL 7 5/8 e� RA @ 3,987' 6-3/4" Hole RA @ 5,438' AA RA @ 6,474' A RA @ 7,470' n� BEL 98 BEL106 7'1 - T8 T11 T12 2 T12 fT17A T18 CASING DETAIL Size Type Wt Grade Conn. ID Top I Btm 16" Conductor -Driven to Set Depth 84 X-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Sud 1,418' 4-1/2' Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAII No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 511-1 ±3,673' CIBP 03/16/19 3 6,881' 3.375" Proposed Permanent Patch 6,881'-6,903'11/06/17 4 8,760' 3.958" CIBP w/ 10' of cement 10/21/17 5 8,950' 3.958" CIBP w/ 26' cement 10/12/17 6 9,012' 1 3.958" CIBP w/ 5' of cement 9/10/17 PFRFnRATI(-)N nFTAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status BEL 98 ±3,656' ±3,673' ±3,156' ±3,170' ±17 Proposed TBD BEL 106 ±3,809' ±3,821' ±3,283' ±3,293' ±12 Proposed TBD T4 ±4,630' ±4,641' ±3,948' ±3,957' ±11 Proposed TBD T8 ±5,058' ±5,105' ±4,308' ±4,348' ±47 Proposed TBD T11 ±5,354' ±5,370' ±4,557' ±4,570' ±16 Proposed TBD T12 5,520' 5,545' 4,692' 4,713' 30 03/15/19 Open T12 5,562' 5,582' 4,727' 4,743' 20 10/13/18 Isolated 6,249' 6,259' 5,298' 5,307' 10 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 1 6 12/14/17 Isolated 6,274 6,285' 5,316' 5,328' 15 12/14/17 Isolated T18 6,418' 6,433' 5,440' 5,452' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T142 8,767' 8,777' 7,677' 7,687' 10 10/13/17 Isolated T1468,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 91033' 7,931' 7,942' 11 07/27/17 1 Isolated f3T43 1 3.80" (3.375" ID) X 21' Owens Tubing Patch F/6,881'-6,903'. TOC @ 8,750 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (1555x)15.4 ppg T142 30/21/iJ f - 4-112- 4 TOC @ 8,9141 �•_� Class G tail. Lost 63 bbls duringjob, 3 bbls of spacer returned to surface. 10/12/17- -. 5 Toc @ 9,00 T146 09/10/17 ....-__. ... ..........- - ' 6 T147 4-1/2" OPEN HOLE / CEMENT DFTAII 7-5/811 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (1555x)15.4 ppg Class G tail. 100% returns throughout, 30 bbis to surface. 4-112- 6-3/4" hole. 240 BBL (675 sx)12,5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls duringjob, 3 bbls of spacer returned to surface. PBTD = 5,555'/ PSTVD = 4,721' TI) =9,265'/TVD =8,173' Updated by DMA 06-27-19 STANDARD WELL PROCEDURE ffilcorp Alaska, LLC NITROGEN OPERATIONS 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 02 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. 12/08/2015 FINAL v1 Page 1 of 1 la,000,00r 1,000,00( r 0 0 CL 100,000 v O 10,000 O w o m Y rc d (� �i 1,000 u Hilcorp Alaska LLC, NINILCHIK UNIT KALOTSA 3 (217-028) NINILCHIK, BELUGA-TYONEK GAS Monthly Production Rates 10 1 Jan 10,000,000 v 1,000,000 0 100,000 0 CID0 0 3 10,000 s 0 t m 1,000 v0—, O G N m 100 ' d) 0 O 10 J 1 ran-cuia Jan -2019 Jan -2020 —A-- Produced Gas (MCFM) = GOR — Produced Water (BOPM) —o— Produced Oil (BOPM) SPREADSHEET_ 2170280_Kalotsa_3_Prod_Cuwes_W ell_Gas_V120_20190718.xlsx 7/18/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 0 4 2019 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing "t Opo 0 Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set CIBP, N2 Q 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Exploratory ❑ Stratigraphic❑ Service ❑ 217-028 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20661-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: C061505 SHL / ADL359242 / ADL384372 TPH/BHL / FEE CIRI Kalotsa 3 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik Field - Beluga/Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,265 feet Plugs measured 5555; 6,239; 9,007 feet true vertical 8,173 feet Junk measured N/A feet Effective Depth measured 5,555 feet Packer measured 1,280 feet true vertical 4,721 feet true vertical 1,203 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A; N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker Swell Pkr 1,280' MD 1,203' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 31 0 Subsequent to operation: 1 0 0 0 22 1286 14. Attachments (required per 20 AAc 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑'r Exploratory❑ Development El Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil L Gas El WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-091 Authorized Name:r•ti `� u---�•T =84 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCalhilcoro.com Authorized Signature: `/ Date: ILI 1 2 131 ( Contact Phone: 777-8420 / 1f RBDMSl Form 10-404 Revised 4/2017 /A �� APR 0 5 2019 Submit Original Only Hilcorp Alaska, LLC. Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E -Line 50-133-20661-00 1 217-028 3/2/19 3/16/19 Daily Operations: 03/02/2019 -Saturday ARRIVE AT PWL SHOP - GATHER TOOLS AND EQUIPMENT - MOB TO LOCATION ON LOCATION -TGSM -JSA- PERMIT RIG UP W/L - PT LUB 2500 PSI - GOOD;RIH W/ 3" X 7' TO 5810'KB WT TO 5823'KB - POOH - OOH W/ MUD RIH W/ SAME TO 5826'KB WT TO 5832 -KB POOH - OOH W/ FULL MUD 6 CUPS MUDDY SAND RIH W/ SAME TO 5827/KB WT TO 5838'KB POOH - OOH W/ MUD NO SAND NOTE: Fluid Level - 3000';RIH W/ 2.5" X 6' DD BAILER TO 5838'KB WT TO 5841'KB POOH - OOH FULL MUD RIG DOWN W/L - MOVE OVER TO KALOTSA 4 (Per Chad E);RIG UP W/L PT LUB - GOOD RIH W/ 2.6" GAUGE RING 9046'KB TAG FILL - POOH RIH W/ 3.8" GAUGE RING TO 9042'KB TAG FILL- POOH - NOTE: Fluid Level at 8750';Rig down off well and turnover to field. Kalotsa 4 cost was put on Kalotsa 3 AFE 03/16/2019 -Saturday Sign in and mobe to location. PTW and JSA. Spot equipment. Start to rig up and found sand and hydrates above swab. Rig up lubricator and pressure test to 2,500 psi with methanol. Open swab slow and heard plug go dawn well. Swab would not open past 9 turns. Closed swab and pumped more methanol and let it soak. Worked swab and got it working right (23 turns). Found master open to 17 rounds. Worked it and got it to 23 turns. RIH w/GPT tool and 3.53" GR, correlated to pert log dated 10-13-18 and tagged at 5,570' (Bottom of open perf). Pulled 300 lbs over string wt to get free. Found fluid level at 4,799' w/1,295 psi on well. Ran correlation log and sent to town to see if we were on depth. POOH. Rig up SLB N2. Pressure test hard lines and lubricator to 4,000 psi. RIH with GPT tool and 3-1/2" OD plug to top of fluid level at 4,799'. Started pumping N2 at 500 scf up to 1,000 scf per min. Checked fluid level twice after 214 gal pumped and 430 gals pumped. Pressure broke over at 1,820 psi and dropped to 1,800 psi. Pumped another 10 min to a total of 650 gals. Fluid had pumped away. Spotted and set top of plug at 5,555'. Picked up 30' and went back down and tagged plug. POOH and everything looked good. When we got ready to run back in with gun we sheared pin in swab. Called wellhead tech and he talked us thru getting swab to open until he can get out here tomorrow. RIH w/ 2-7/8" x 25' Razar HC, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Get ok to perf from 5,520' to 5,545'. Bled well down to 1,305 psi. Spotted and fired gun. After 5 min - 1,308.7 psi, 10 min - 1,307 psi and 15 min - 1,306.7 psi. Fired gun at 1937 hrs. POOH. All shots fired and gun was dry. There is a drop in pressure because we couldn't get swab or middle master to hold while bleeding off lubricator. It dropped to 1,273 psi at 2109 hrs. Rig down lubricator and equipment and turn well back over to field. LI/ 16" Ninilchik Unit SCHEMATIC PTD PTD::2177-- 11 2028 API: 50-133-20661-00 Ililcmp Alenke. LLC RKB to GL= 19.1' RA @ 7,470' ^ a CASING DETAIL Size Type Wt Grade Conn. ID Top } 16" 6-3/4" �: X-56 Hole 15.01" Surf 120' i; Surf Csg RA @ 3,987' L - BTC 6.875" 7_ 1,418' 4-1/2" r 12.6 RA @ 5,438' 3.958" Surf 9,252' T17A 6,259' 6,265' 5,307' RAP 6,474' 6 12/14/17 RA @ 7,470' ^ a 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 - BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-8080 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 t 5,560' 5,545' CIBP 3 6,881' 3.375" 03/15/19 Permanent Patch 6,881'-6,903'11/06/17 4 8,760' 3.958" CIBP w/ 10' of cement 10/22/17 5 8,950' 3.958" CIBP w/ 25' cement 10/12/17 6 9,012' 3.958" Cl BP w/ 5' of cement 9/10/17 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T12 5,520' 5,545' 4,692' 4,713' 130 03/15/19 Open T12 5,562' 5,582' 4,727' 4,743' 20 10/13/18 Isolated T146 6,249' 6,259' 5,298' 5,307' 10 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 6 12/14/17 Isolated 4-1/2"1..._ 6,270' 6,285' 5,316' 5,328' 15 12/14/17 Isolated T18 6,418' 6,433' 5,440' 5,452' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T1428,767' 8,777' 7,677' 7,687' 30 10/13/17 Isolated Ti46 8,975'7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T12 2 C-tBP T12 T17A T18 T43 3.80" (3.375" ID) X 21' Owens Tubing Patch 3 F/6,881'-6,903'. TOC@8,750' �" Class G tail. 100% returns throughout, 30 bbls to surface. T142 10/21/17 I• -4 Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. TOC @8,950 w•___ 10/12/1 ,`- _ 5 TOC@9,007 �'- T146 09/10/1] - 6 T147 4-1/2"1..._ p M PBTD = 5,555'/ PBTVD = 4,721' TD = 9,265'/TVD = 8,173' OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112" 6-3/4" hole. 240 BBL (675 sx) 12.5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by DMA 04-03-19 DATE 3/27/2019 Debra _udean Hilcorp Alaska, LLC 30 50 GeoTech 3800 Centerpoint Drive Anchorage, 99503 Tele: 907 77777 -8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 PERFORATION RECORD 10 OCT 2018 KALOTSA 3_PERF_10QCT18_Correlation . KALOTSA 3_PERF 10OCT18 Shooting KALOTSA_3 PLUG_10OCT18_�ti Seng KALOTSA 3 PLUG -PERF 10OCT18 µ' KALOTSA 3_PLUG-PERF_100CT78_FluidL... E� KAL0TSA_3 PLUG-P€RF_10OCT18 img 11/14/2018 9:52 AM LAS File 11/14/20189:52AM LASFte 11,/14/20189:52AM LASFile 11/14/2018 9:52 AM PDF Document 11/14/201810:14... LAS File 11t114+20189:52AM TIFFFile Please include current contact information if different from above. SCANNED MAR 1 01019 RECEIVED MAR 2 8 2019 AOGCC 98 KB 75 KB 62 KS 1,876 KB 275 KB 2,648 KB Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 3 Permit to Drill Number: 217-028 Sundry Number: 319-091 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a og c c.a a ska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED thisZ�day of February, 2019. RBDMSIOANAR 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 25 2019 AIDG . 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: Set CIBP, N2 ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑Q . Stratigraphic ❑ Service ❑ 217-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20661-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C0 701C No • Will planned perforations require a spacing exception? Yes Li No Ninilchik Unit Kalotsa 3 ' 9. Property Designation (Lease Number): 10, Field/Pool(s): C061505 SHL / ADL359242 / ADL384372 TPH/BHL / FEE CIRI Ninilchik Field - Beluga/Tyonek Gas Pool ' 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,265' 8,173' 8,750' 7,660' -1,590 psi 9,012; 8,950 & 8,760 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation Depth MD (ft):Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Pkr; N/A 1,280' MD/1,203' TVD; N/A 12. Attachments: Proposal Summary ❑Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 1, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑Q ` WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Be York 7774345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: [kramerColhilcoro corn {- ` Contact Phone: 777-8420 Z o 7 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: ro-yp t RMS-A&MAR 0 5 2019 A/PPROVED BY COMMISSION Date: Approved by: COMMI961?ln JHJ Z � v r i \r-\ 'I [A 1011VAL Submit Form and r Att chments in uplicate Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. tib OjK9 - 7-7,/9 H Hilcora Alaska, LU Well Prognosis Well: Kalotsa #3 Date: 9/26/2018 Well Name: Kalotsa #3 API Number: 50-133-20661-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: March 1, 2019 Rig: E -line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Maximum Expected BHP: - 2,061 psi @ 4,717' TVD (Based on normal gradient of 0.437 psi/ft and the lowest perforation) Max. Potential Surface Pressure: - 1,590 psi @ 4,717' TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary The lower T-12 was perforated in the Kalotsa # in October 2018. Initial production was 6 MMscfd but water gradually came in over the next 3 months and the well loaded up and died. The purpose of this work/sundry is to push the water back into the lower T-12 perforations and set a plug. The upper T-12 will then be perforated to see if there is gas above the water that can be recovered. Notes Regarding Wellbore Condition • A CBL ran July 8, 2017 shows excellent cement covering the T-12 sand. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Considertank placement based on wind direction and current weather forecast (venting Nitrogen during this job) • Ensure all crews are aware of stop job authority Pre -Sundry Work 1. MIRU Slickline. Pressure Test Lubricator to 2,500 psi. 2. RIH W/ 2-3/8" GS retrieving tool and retrieve temporary plug @ 6,239'. E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 3,000 psi Hi 250 Low. 2. RU Nitrogen Truck. Pressure up on well and push water back into formation. Use GPT tool to confirm Water level is below 5,550'. 3. PU RIH With 4-1/2" CIBP to 5,560' (+/-) and set same making sure we are above all perforations. Note: No cement will be placed on this plug due to there not being enough room from it to the new perforations. 4. Pressure up well to 1,300 psi. Well Prognosis Well: Kalotsa #3 Mears Alaska, LL' Date: 9/26/2018 5. Perforate the T-12 Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns (up to 12 SPF with 2 perf runs) 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 6. POOH. 7. RD a -line. 8. Turn well over to production. (Test SSV with -in S days of stable production on well — notify AOGCC 24hrs before testing) E -line Procedure (Contingency): 1. if this zone produces sand and/or water or needs isolated 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 3. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure—N2 Operations Zone Sand Top(MD) Btm(MD) Top(TVD) I Btm(TVD) I Amt Tyonek T12 ±5,520' ±5,550' ±4,692' ±4,717' 30' 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 6. POOH. 7. RD a -line. 8. Turn well over to production. (Test SSV with -in S days of stable production on well — notify AOGCC 24hrs before testing) E -line Procedure (Contingency): 1. if this zone produces sand and/or water or needs isolated 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 3. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure—N2 Operations 16" Ninilchik Unit KaloSCHEMATIC PTD: a 2177-- PTD: 028 API: 50-133-20661-00 Flikry Alwke, LLC RKB to GL= 19.1' r'. 6-3/4„ i Hole Grade Conn. •• RA@3,987' ^r RA @ 5,438' Conductor - Driven to Set Depth 84 x-56 Weld 15.01" Surf a' RA @ 6,474' RA @ 7,470' .f TOC @ B,J50' 10/21/17 - TOC @ 8,9so 10/12/1 TOC @ 9,007' ' 09/10/17 _. 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 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 6,239' 3.985" EVO-Triev Plug 10/13/18 3 6,881' 3.375" 10/13/18 Permanent Patch 6,881'-6,903' 11/06/17 4 8,760' 3.958" CIBP w/ 30' of cement 10/22/17 5 8,950' 3.958" CIBP w/ 25' cement 10/12/17 6 9,012' 3.958" CIBP w/5'of cement 9/10/17 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T12 5,562' 5,582' 4,727 4,743' 20 10/13/18 Open 6,249' 6,259' 5,298' 5,307' 10 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 6 12/14/17 Isolated 6,270' 6,285' 5,316' 5,328' 35 12/14/17 Isolated T18 6,418' 6,433' 5,440' 5,452' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T142 8,767' 8,777' 7,677 7,687' 10 10/13/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T12 2 T17A T18 T43 FF/60881' (3.375" ID) X 21' Owens Tubing Patch 3 - 6,903'. T142 4 5 T146 6 T147 4-1/2"L ' 1/2 L' I - - PBTD = 6,239'/ PBTVD = 5,290' TD = 9,265'/ TVD = 8,173' OPEN HOLE/ CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112" 6-3/4" hole. 240 BBL (675 sx) 12.5 Type 1-11 cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by DMA 02-25-19 RKB to GL= 19.1' 6-3/4" Hole RA @ 3,987' RA @ 5,438' s RA@6,474' AA RA @ 7,470 :4 TOC@ 8,750' 10/21/17. PROPOSED SCHEMATIC CASING DETAIL Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 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 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 UP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 15,560! [5,550' CIBP 3 6,881' 3.375" Proposed Permanent Patch 6,881'-6,903'11/06/17 4 8,760' 3.958" CIBPw/ 30' of cement 10/22/17 5 8,950' 3.958" Cl BP w/ 25' cement 10/12/17 6 9,012' 3.958" Cl BP w/ 5' of cement 9/10/17 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (ND) Btm (TVD) Ft Date Status T12 ±5,520' [5,550' ±4,692' ±4,717' ±30 Proposed TBD T12 5,562' 5,582' 4,727' 4,743' 20 10/13/18 Isolated 6,249' 6,259' 5,298' 5,307' 30 11/06/17 Isolated T17A 6,259' 6,265' 5,307' 5,312' 6 12/14/17 Isolated 6,270' 6,285' 5,316' 5,328' 15 12/14/17 Isolated T18 6,418' 6,433' 5,440' 5,452' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T342 8,767' 8,777' 7,677' 7,687' 10 10/13/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 31 107/27/17 Isolated T12 T12 =� T17A T18 T43 3.80" (3.375" ID) X 21' Owens Tubing Patch F/6,881' - 6,903'. T142 4 5 -^ T146 6 - }- T147 OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112' 6-3/4" hole. 240 BBL (675 sx) 12.5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. PBTD = 6,239'/ PBTVD = 5,290' TD = 9,265'/ TVD = 8,173' Updated by DMA 02-25-19 STANDARD WELL PROCEDURE I fflcorp Alaska. LLC NITROGEN OPERATIONS 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 02 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. 12/08/2015 FINAL vl Page 1 of 1 THE STATE 01ALASKA GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Cas Conservation Commission Re: Ninilchik Field, Beluga-Tyonek Gas Pool, Ninilchik Unit Kalotsa 3 Permit to Drill Number: 217-028 Sundry Number: 318-437 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this 3 4ay of October, 2018. Sincerely, 4Cay$QoeArsterj1-�— Commissioner D-a<6U0 1lo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SEP 2 S 20E3 O t•S ,'se's.CC J-.... 1. Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N2 Operations/Pump Truck ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 10, Stratigraphic ❑ Service ❑ 217-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20661-00-00 7. If perforating: 7v/ 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO Will planned perforations require a spacing exception? Yes ❑ No ❑� /�/• 7 Ninilchik Unit Kalotsa 3 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): C061505 SHL / ADL359242 / ADL384372 TPH/BHL / FEE CIRI Ninilchik Field - Beluga/Tyonek Gas Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,265' 8,173' 8,750' 7,660' -1,884 psi - 9,012; 8,950 & 8,760 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 12U 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Pkr; N/A 1,280' MD/1,203' TVD; N/A 12. Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 12, 2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS Q WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tk112191 o'lhilcoro.com Contact Phone: 777-8420 p Authorized Signature: Date: O COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: r99pIe 9 ZN1R Post Initial Injection MIT Req'd? Yes ❑ No F1,IIGJ`y� -- a y Rho Spacing Exception Required? Yes ❑ No Subsequent Form Required: / Q \1 ,.,j APPROVED BY Approved by:/L.\ OMMISSIONER THE COMMISSION Date: JU`V�VY v /V -.Re/Q•�.rj V /� ^ � � Submit Form and Form 10-403 Revised 4/2017 Approved application is a {`rr�r/ a ate of approval. �/ /Attachments in uplicate t- H Hamra Alaska, LU Well Prognosis Well: Kalotsa #3 Date:9/26/2018 Well Name: Kalotsa #3 API Number: 50-133-20661-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: October 12th, 2018 Rig: E -line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary — 2,093 psi @ 4,741' TVD — 1,884 psi @ 4,741' TVD Kalotsa #3 is a gas producer that was completed in September of 2017. (Based on normal gradient of 0.437 psi/ft and the lowest perforation) (Based on expected BHP and gas gradient to surface (0.10psi/ft) The purpose of this work/sundry is to set a plug above the T17A and perforate the T-12 sand. Notes Regarding Wellbore Condition • A CBL ran July 8, 2017 shows excellent cement covering the T-12 sand. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) • Ensure all crews are aware of stop job authority E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. 2. Run GPT tool to determine the fluid level (if any). 3. Pressure up on well to push fluid level below 5,600'. Note: Nitrogen may be used to pressure up well.) 4. PU RIH W/ 4-1/2" CIBP and set at 6,240'. p / 5. Pressure up well to 1,500 psi. q NL A:510k 6. Perforate the T-12 Tyonek sands with 2-7/8" 6 SPF 60 deg phased pert guns (up to 12 SPF with 2 perf runs) Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Tyonek T12 ±5,560' ±5,580' ±4,725' ±4,741' 20' 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. Well Prognosis Well: Kalotsa #3 f ].o pAlaska, LL Date: 9/26/2018 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. f. Rule 2 of Conservation Order 701A defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 7. POOH. 8. RD a -line. 9. Turn well over to production. (Test SSV with -in 5 days of stable production on well -notify AOGCC 24hrs before testing) E -line Procedure (Contingency): 1. If this zone produces sand and/or water or needs isolated 2. MIRU Nine, PT lubricator to 3,500 psi Hi 250 Low. 3. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure - N2 Operations Hilcorp Aleelu, LLc 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx)15,4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. Ninilchik Unit KaloSCHEMATIC PTD: d 2177-- PTD: 028 API: 50-133-20661-00 RKB to GL= 19.1' Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. _ Toe @8,750'.,. IU/21/ll �•'1 T142 � TOc @ 8,950 10/12/1 4 CASING DETAIL 1�. n 5 Size Type Wt Grade Conn. ID Top Btm 16" Conductor - Driven 84 X-56 Weld 15.01" Surf 120' - to Set Depth '' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' ' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer - 2 6,881' 3.375" Permanent Patch 6,881'-6,903'11/06/17 3 8,760' 3.958" CIBP w/ 10' of cement 10/22/17 4 8,950' 3.958" CIBP w/ 25' cement 10/12/17 - 1 5 9,012' 3.958" CIBP w/ 5' of cement 9/10/17 •'r PERFORATION DETAIL `. �. Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status 6,249' 6,259' 5,246' 5,229' SO 11/06/17 Open T17A 6,259' 6,265' 6 12/14/17 Open 6,270' 6,285' 15 12/14/17 Open 4_ T18 6,418' 6,433' 15 02/07/18 Open T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated - T142 8,767' 8,777' 10 10/13/17 Open 6-3/4" T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated Hole - T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated RA @ 3,987' a RA@5,438' u . r RA@6,474' 4lA a = r T17A _ T18 T43 3.80" (3.375" ID) X 21' Owens Tubing Patch 2 F/6,881'-6,903'. RA @ 7,470' C' 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx)15,4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112- 6-3/4" hole. 240 BBL (675 sx)12,5 Type 1 -II cement, followed with 32 BBL (160sx) of s Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. _ Toe @8,750'.,. IU/21/ll �•'1 T142 � TOc @ 8,950 10/12/1 4 TOC@9,007' �" T146 n 5 - F147 PBTD = 8,750'/ PBTVD = 7,660' TD = 9,265' / TVD = 8,173' OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx)15,4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112- 6-3/4" hole. 240 BBL (675 sx)12,5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by DMA 11-03-17 Ninilchik Unit PROPOSED PTD PTD:: 2177-- 2028 API: 50-133-20661-00 Hikory Alaska, LLc RKB to GL= 19.1' RA @ 7,470' Type 7 5/8„ Grade 6-3/4" IF Hole Btm TOC @8,750• r S. RA@3,987' as Q RA @ 5,438' , a 10/12/1 ,t 7-5/8" 5urfCsg TOC@9,007 L-80 RA @ 61474' t Surf 1 4-1/2" Prod Csg 12.6 L-80 RA @ 7,470' Type Wt Grade Conn. t�. Top Btm TOC @8,750• Conductor - Driven to Set Depth 10/21/17 X-56 TOC @ 8,950 15.01" 10/12/1 120' 7-5/8" 5urfCsg TOC@9,007 L-80 09/10/17 "� Surf 1 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" 5urfCsg 29.7 L-80 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 UP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 ±6,240' 3.985" CIBP 3 6,881' 3.375" Future Permanent Patch 6,881'-6,903'11/06/17 4 8,760' 3.958" CIBP w/ 10' of cement 10/22/17 5 8,950' 3.958" CIBP w/ 25' cement 10/12/17 6 9,012' 3.958" CIBP w/ 5' of cement 9/10/17 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T12 ±5,560' ±5,580' ±4,725' ±4,741' ±20' Future Proposed 6,249' 6,259' 5,246' 5,229' 10 11/06/17 Isolated T17A 6,259' 6,265' 6 12/14/17 Isolated 6,270' 6,285' 15 12/14/17 Isolated T18 6,418' 6,433' 15 02/07/18 Isolated T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T142 8,767' 8,777' 10 10/13/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' it 07/27/17 Isolated T12 S T17A T18 T43 1 3.80" (3.375" ID) X 21' Owens Tubing Patch F/6,881'-6,903'. T142 4 5 T146 6 T147 OPEN HOLE/ CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112' 6-3/4" hole. 240 BBL (675 sx)12,5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. PBTD = 8,750'/ PBTVD = 7,660' TD = 9,265' / TVD = 8,173' Updated by J LL 09/26/18 STANDARD WELL PROCEDURE I lilrnrp Alaska, LLC NITROGEN OPERATIONS 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/CC2/C2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 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. 12/08/2015 FINALvl Page 1 of 1 . RECEIVED STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATIONS MAR 12 2018 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing Li ° OLCCjwn U Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ =rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 217-028 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 50-133-20661-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: C061505 SHL/ADL359242/ADL384372 TPH/BHL Kalotsa 3 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Ninilchik Field-Beluga/Tyonek Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,265 feet Plugs measured 9,007 feet true vertical 8,173 feet Junk measured N/A feet Effective Depth measured 9,007 feet Packer measured 1,280 feet true vertical 7,916 feet true vertical 1,203 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic SPb S 040414E°I True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A; N/A N/A Packers and SSSV(type,measured and true vertical depth) Baker Swell Pkr 1,280'MD 1,203'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 52 0 0 135 Subsequent to operation: 0 133 0 41 48 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-310&318-006 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com Authorized Signature: 64/"..../ ...._....., Date: vI Z, I Contact Phone: 777-8420 Form 10-404 Revised 4/2017 71 ?'Z1 f�a RBDIS w K AE , sd 2C18 Submit Original Only dt /Zgl1k. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E-Line 50-133-20661-00 217-028 7/8/17 2/13/18 Daily Operations: 07/08/2017 -Saturday PTW and JSA. Spot equipment and MU 3-1/2"junk basket. RIH w/3-1/2"JB and tag at 9,080' KB. The tag was not correlated. SLB didn't have the gama ray to run with JB. POOH. No problems. Switch over the Kalotsa #4. MU and RIH with CBL, correlate to OHL and tag at 9,135'. Seems like we set down on stringer with the 3-1/2"junk basket. We couldn't get rough with junk basket due to no gauge ring on JB. The CBL tool is 1-11/16 OD. Log to 80'. Rig down CBL tool and lay crane over. Will be back at 7am to run PNX log. 07/20/2017 -Thursday Obtain PTW. Hold safety meeting. Discuss job procedure and review JSA with crew. MIRU SLB CTU 13 with 1.75" CT. Hook field triplex to IA. (7-5/8" x 4-1/2") 400 psi out of fluid. Wait for production operator to fill triplex. Continue to pressure up to 2,500 psi. Bleeding down. Bleed back to tank and allow air to escape. Repeat 3 times. Pressure dropping less each time. 24 BOPE test witness notification sent 7/19/17 @ 12:24PM. Witness waived by Jim Regg 7/19/17 @ 12:29 PM. Start BOPE test. Accumulator draw down test.Test all rams and valves 250-300 psi Low and ,4000 psi high. BOPE test complete. Pressure up IA to 2,630 psi for 30 minutes. End pressure 2.500 psi. 130 psi loss over 30 minutes. Less than 5% losses over test time. Bleed IA down to tank. Pressure up IA to 2,678 psi. Shut in. Leave coil Cat acquisition running throughout the night to monitor and record IA pressure. Locations secure. SDFN. 07/21/2017 - Friday Obtain PTW. Hold safety meeting. Review and discuss job procedure. Air liquid N2 transport on location with 6,002 gallons of N2. Pressure up IA to 2,700. Shut in and monitor pressure in CT ops cab. Pick injector head. Stab 10' lubricator. Make up BHA and ball drop nozzle for reverse N2 lift. Stab on well. PT stack 250/4,000 psi. Bleed down. Open master swab 23.5 turns. RIH. Start cooling down N2. Online N2 down CT annulus. 800 scf/min @ 3,500' CTMD. Walk up rate slowly to 1,500 scf/min. Tag PBTD @ 9,142' CTMD. 9,149' RKB corrected depth. Started seeing returns to surface at 8,800' CTMD. WHP 2,300 psi. Circ 23. Stay on bottom lifting fluid with N2. WHP peak was 3,450 psi. Tank strapped shows 147 bbls in return tank. Well blown dry. Continue to pump for 10 minutes while N2 at surface. Shut in choke and start POOH while pressuring up well to 3,000 psi. 187,000 scf/2,008 gal for unloading well bore fluid. 81,000 scf/870 gallons used to pressure 4.5" tubing up to 3,000 psi. Total fluid returned 147 bbls. Total N2um ed p p 268,000 scf or 2,878 gallons. Shut down N2. Continue to POOH to surface. Tagged up. Close master/swab. Final SITP 3,090 psi. Bleed down N2. Rigdown SLB CTU 13 and move to Kalotsa #4. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E-Line 50-133-20661-00 217-028 7/8/17 2/13/18 Daily Operations: 07/27/2017 -Thursday PTW and JSA. Rig up lubricator and MU 1-11/16" Press/Temp tool. PT to 250 psi low and 3,500 psi high. TP- 2,988.5 psi. RIH with Press/Temp tool and tie in to OHL.Tagged at 9,148' and found fluid level at 9,141'. POOH RIH w/2-7/8" x 4' HC, 1 spf, 60 deg phase and tied into OHL. Ran correlation log and send to town. Get ok to perf from 9,022' to 9,026'. Spotted and fired gun with 2,961.1 psi on tubing and after five minutes pressure was 2,960.7. POOH. All shots fired and gun was dry. Re-head line. RIH w/3-3/8" x 11' HC Razor, 6 spf, 60 degree phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9,022'to 9,033'. Spot and fired gun with 2,847.1 psi on well. After 5 min TP was 2,848. The reason TP was^'100 less than first run was mainly due to we pressured up Kalotsa 2 with N2 to 2,000 psi off of 3 to pull the plug at 500'. POOH. All shots fired and gun was dry. Rig down lubricator and move to Kalotsa #2. TP- 2,835.8 psi. 08/25/2017 - Friday RU HES E-line. Stab on well. PT stack 3,500 psi. RIH with GPT/CCL to look for fluid level. Found fluid level 77' lower than wednesday PT survey. Fluid was at 8,302'. Called town to discuss (previous fluid level 2 days earlier was 8,225'). Flow Kalotsa 4 and re group for N2 on Kalotsa. Monday SLB N2 pressure up to 4K. Rig back equipment. 2,620 SITP. SDFN. Location secure. NOTE: Started attempting to push fluid away by shutting in Kalotsa #4 production and jumping pressure to Kalotsa # 3 at 15:00 hrs 8/24/17. Fluid level at that time was 8,225' MD. WHP on K-3 when started build up was 180 psi until we tagged fluid 8,302' 8/25/17 @ 12:30. 21.5 hours of pressure build pushed fluid 77' into formation. Formation is tight. 08/28/2017 - Monday Obtain PTW. Hold safety meeting and discuss job procedure and pressure limitations. MIRU SLB N2 Float. Transfer N2 from Air Liquid transport. Cool down N2 pump. Rig up 1502 iron (1502 N2 iron rigged to HES wire line valve 1502). PT stack to 250/4,500 psi. Bleed down. Open well. Initial WHP 2,610 psi (pressure build from Kalotsa #4). Online with N2 at 800 scf/min at 0830. Average N2 temp 100*F. 0925 hrs WHP/pump pressure 3,800 drop N2 rate to as slow as it can pump. 400 scf/min. Pressure still climbing. Shut down N2 at 4,060 psi @ 0930. Well shut in. Monitoring pressure. 1.5 hours WHP still 4,030 psi. Holding like a rock. Doesn't look like we are pushing fluid away very fast. Formation is tight. Online with N2 pressure up well to 4,200 psi, shut down N2. 11:15 hrs. Shut in swab, upper and lower master valves. Final SITP 4,206 psi. Rig down SLB N2 pump. Total N2 pumped. 62,000 scf or 665 gallons. 3,000 gallons of N2 available. Well was shut in at 11:15 hrs. Prior to departing location at 12:10 WHP was still 4,206 psi. Plan forward is to let well sit for up to one week and attempt PT/survey to check for fluid level. 08/31/2017 -Thursday PTW and JSA. Rig up lubricator. PT to 250 psi low and 4,500 psi high. RIH w/ Press/Temp tool and tie into perf log. Tagged 9,164'. Found fluid level at 8,982'. POOH. Rig down lubricator and turn well over to field. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E-Line 50-133-20661-00 217-028 7/8/17 2/13/18 Daily Operations: 09/10/2017 -Sunday Mobe to location. PTW and JSA. Rig up Lubricator. PT to 250 psi low and 4,500 psi high. RIH w/3.74" CIBP and tie into OHL. Run correlation log and send to town. Get ok to set plug at 9,012'. Spotted plug and set at 9,012'. Lost 180 lbs of line tension. Pick up 30' and go back and tag plug. POOH. Good set.TP- 3,000 psi when plug was set. RIH w/3-1/2" x 20' bailer filled with 4 gals of cement (7') and tag plug at 9,012'. Pick up and dump cement on plug. Lost 30 lbs line tension when cement dumped. POOH. Good dump. Est TOC 9,007'. CIP is 1230 hrs. Rig down lubricator and WOC. 09/26/2017 -Tuesday Mobe to location. PTW and JSA. Rig up Lubricator, PT to 250 psi low and 4500 psi high. TP- 2400 psi. RIH w/GPT tool, tie into OHL and tag at 9008'. Found fluid level at 9004' with 2400 psi on well. POOH. RIH w/2-7/8"x20' Razor HC, 6spf, 60 deg phase perf gun, tie into OHL and tag at 9008'. Run correlation log and send to town. Bleed well down to 2234 psi. Get ok to perforate from 8975' to 8995'. Spotted gun and fired with 2234 psi on tubing. After 5 min pressure was 2235.2 psi, 10 min was 2234.8 psi and 15 min - 2234.1 psi. POOH. All guns fired and gun was wet. Rig down lubricator and turn well over to field. 10/12/2017-Thursday Mobe to location. PTW,JSA and SIMOPS w/Pollard E-Line and SLB N/2. Rig up Lubricator and hard line. PT to 250 psi low and 4,500 psi high. TP- 143 psi. RIH w/GPT tool and tie into Perf log dated 9-26-17 and tagged at 9,005'. Found fluid level at 8,940' with TP at 143 psi. Ran GPT log and send to town. POOH. RIH w/3-1/2" CIBP and tie into GPT log ran today. Ran correlation log. Spotted plug at 8,950' and set plug with 140 psi on well. Lost 100 lb line tension when plug set. Pick up 30' and go back and tag plug. POOH. Setting tool look good. Started pressuring up well. Pressure tubing up to 2,450 psi. Mix up cement. RIH w/3" x 30' dump bailer loaded with cement (9 gals). Ran out of grease at 4,800'. Shut pack-off pump more grease in drum. Went on down hole and dumped cement on top of plug at 8,950'. POOH. Good dump.TP- 2,392 psi. Lost some pressure when we lost seal on grease. RIH w/3" x 30' dump bailer loaded with cement (6 gals) and dumped cement on plug at 8,950'. POOH good dump. 16.6 lb/gal Est TOC at 8,925' and CIP at 0100 hrs. Rig lubricator off well and secure well. Will be back around noon tomorrow to perforate.TP- 2,375 psi. 10/13/2017- Friday Mobe to location. PTW,JSA. Rig up lubricator,PT to 250 psi low and 4,500 psi high.TP- 2,370 psi. RIH w/2-7/8" x 10' HC Razor, 6 spf, 60 deg phase perf gun and tie into OHL.Tagged TOC at 8,924'. Run correlation log and send to town. Get ok to perf the T 142 zone from 8,767' to 8,777'. Spot gun and fire with 2,361.6 psi on tubing. After 5 min -2,362.6 psi, 10 min - 2,362.1 psi, 15 min - 2,360.6 psi. POOH. All shots fired and gun was dry.TP- 2,347.9 psi. Rig down lubricator and turn well over to field. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E-Line 50-133-20661-00 217-028 7/8/17 2/13/18 Daily Operations: 10/14/2017-Saturday Arrive at PWL Shop,pickup tools crew and equipment head to Susan Dionne. Arrive at Susan Dionne. Meet with Dave, talk about well work, do permit and JSA. Move to Kalotsa. Rig up slickline. P/T LUB and WLV 3,500 psi, GOOD. RIH w/2.8" G-ring to at approx 3,400', start falling very slow, most likely due to deviation or E-line grease, possiblity of both, continue to 4,400' KB. POOH. Falling very slow.Add roller boggles, new String is RS LSTEM Roller B, Stem Roller B KJ OJ Roller B LSSJ Roller B. RIH w/same to 5,500' KB, start falling slow, pickup speed around 8,470' KB continue to 8,965' wlm, wit can't pass. POOH, OOH, lots of E-line grease in G-ring. RIH w/tandem pressure temp gauges to 8,787' KB, fall as slow as 30' fpm in most of run due to deviation and E-line grease even with roller boggies, once on btm, do 10 min stop while production bleeds well from 1,175 to 900 psi, continue POOH from 8,000' at 120 fpm to surface, see stop sheet for detail. OOH, download data and send to Jerry Butler, data GOOD. Rig down, clean and secure area and wellhead. Turn in permits and leave location. Arrive at PWL shop. 10/20/2017 - Friday Mobe to location. PTW,JSA. Rig up Lubricator, PT to 250 psi low and 4,500 psi high.TP- 1,260 psi. RIH w/GPT and 3-1/2" CIBP and tie into OHL. Found FL at 6,940' and gassy fluid to 6,900'. Ran correlation log from 6,750' to 7,220' to make sure we were on depth. Send log to town followed by phone call. Decision was made to dog off job today and pressure well back up from Kalotsa 4. POOH. Rig down lubricator and turn well over to field. Will come back in the morning. 10/21/2017-Saturday Mobe to location. PTW,JSA. Rig up Lubricator, PT to 250 psi low and 4,500 psi high. TP - 1,211 psi. Yesterday pinched back Kalotsa 4 to build up pressure so we could pressure up Kalotsa 3. Started pressuring up at 1900 hrs and well broke over at 1,912 psi at 2140 hrs. Kept pushing gas in Kalotsa 3 for 2-1/2 hrs to make sure water was pushed into perfs. RIH w/3-1/2" CIBP and GPT tool and tie into OHL. Ran correlation log and send to town. Found fluid level at 6,840'. Called town and discussed. SLB. N2 pump truck was still on location with approx. 1,000 gal of N2. POOH up into lubricator with GPT/Plug. Rig up N2 lines and pressure test hard lines and lubricator to 4,500 psi and open up to well. Start pressuring up well from 1,900 psi to 4,150 psi with approx. 850 gals of N2 when we ran out. Found fluid level at 6,950'. Call town and RIH and set plug at 8,760' correlated with 3,894 psi on tubing. Lost 50 lb line tension when plug set. PU 30' and went back down and tagged plug. POOH. Log fluid level and it pushed away 40' more of fluid. FL is 6,990'. Will be 6,980' after dump bailing 10' of cement. POOH. Bleed tubing to 2,000 psi. RIH w/3" x 20' cement dump bailer and tag plug at 8,760'. Pick up and attempted to dump bail cement on plug. Got out of hole and cement had not dumped. Mix another batch of cement and went back in hole and tag plug at 8,760'. PU 17' and dumped bailed 10' cement on top of plug. POOH. Good dump. CIP at 1845 hrs. Est TOC at 8,750'. 1,927 psi. on tubing. RIH w/2-7/8" x 12' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 6,887' to 6,899' off correlation log (per Jacob Dunston). Spot and fire gun with 1,868.4 psi. Went to 1,874 psi. 5 min - 1,878.8 psi, 10 min - 1,881.4 psi and 15 min - 1,883 psi. Fired gun at 2023 hrs. Rig down lubricator and turn well over to field. TP- 1,890.3 psi.All shots fired and gun was dry. • i Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E-Line 50-133-20661-00 217-028 7/8/17 2/13/18 Daily Operations: 11/06/2017- Monday PTW,JSA and SIMOPS with Pollard and SLB. Spot equip and rig up N2 hard lines and lubricator. PT to 4,700 psi.TP- 1,950 psi. RIH w/GPT and 3.83" GR and tie into Pollard perf log. Found fluid level at 5,540' and went down hole and sat down on perfs at 6,895'. Picked up and went on down with no problem to 7,000'. Ran GPT/GR log up to 6,690'. Started pressuring up tubing from 1,950 psi to 4,500 psi and let pressure go down to 4,000 psi then pressure up again to 4,500 psi. Did that several times until fluid level got to 6,850'. Pressured up to 4,500 psi and POOH. Rig down SLB N2 lines and released them. MU 3.80" (3.375" ID) x21' Owens Tubing Patch. RIH with tubing patch and tie into GPT/GR log. Patch set down once at 6,890'. Picked up and went back thru perfs ok. Got on depth and set patch from 6,881.5' to 6,903' with 2,900 psi on tubing. Lost 350 lbs when patch set. Picked up 10' and sat back down on plug. POOH. Setting tool looked good. RIH w/GPT, 2-7/8" x 10' Razor HC, 6 spf, 60 deg perf gun and tie into OHL. Bled pressure down to 1,600 psi. Find fluid level at 6,884'. Run correlation log and send to town. Get ok to perforate from 6,249' to 6,259' (T17A Sand). Fired gun with 1,613.9 psi on tubing. Pressure went to 1,615.4 psi after 5 min, 1,615.1 psi after 10 min and 1,614.4 psi after 15 min. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field. TP - 1,608 psi. 12/14/2017-Thursday Mobe to location. PTW,JSA. Rig up Lubricator. PT to 250 psi low and 4,500 psi high.TP-743 psi. RIH w/2-7/8" x 31' HC Razor(6' loaded, 5' blank, 15' loaded) 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Down shifted 1' and get ok to perf. Spotted and shot gun from 6,259' to 6,265' and 6,270' to 6,285' with 804.5 psi. 5 min - 818.1 psi, 10 min - 826 and 15 min -838.3 psi. POOH. All shots fired and gun was dry. Rig lubricator to Kalotsa 4 and turn well over to field. 02/05/2018- Monday Sign in. Mobe to location, PTW and JSA. PT to 250 psi low and 4,500 psi high.TP - 1,260 psi. RIH w/GPT, 3-1/8" x 10' sample bailer and tie into OHL. Found FL at 6,495'. Ran log and send to town. POOH. No problems. Left fluid sample at office. RIH w/ CCL-GR, 2-7/8" x 20' (15' loaded with charges) and tie into OHL. Started log at 6,540' and was running correlation log and tools hung up 6,259' (bottom of T17A perfs 6,249 to 6,259'). Couldn't go up or down. Call town and discussed. Worked tools and finally got them to move down. Worked tools up until finally got out of open perfs. POOH. Couldn't really see what had tools stuck. We also pressured K3 up to 1,710' from K2.The plan is to put slickline on well in the morning while E-line goes to perf SCU 31-04. Get tight spot from 6,249'to 6,259' cleaned up and come back Wednesday and perforate. Rig down lubricator and turn well over to field. 02/07/2017-Wednesday Sign in. Mobe to location. PTW and JSA. Spot equipment rig up lubricator. PT to 250 psi low and 4,500 psi high. TP- 1,536 psi. RIH w/2-7/8" x 15' Razor HC, 6 spf, 60 deg phase perf gun and tie into OHL. Run correlation log and send to town. Get ok to perf from 6,418'to 6,433'. Pressure up tubing from 1,536 psi to 1,708 psi from Kalotsa 2. Spot and fire gun w/ 1,708 psi on tubing. After 5 min - 1,698 psi, 10 min - 1,690 psi and 15 min - 1,682 psi. we lost 250 lbs when gun was fired but wasn't blown up hole. Picked wt right back up. POOH. All shots fired and gun was dry. Didn't have any trouble running in hole or pulling out of hole. Rig down lubricator and turn well over to field. TP- 1,628.8 psi. • . . • IIHilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3 E-Line 50-133-20661-00 217-028 7/8/17 2/13/18 Daily Operations: 02/13/2018-Tuesday Sign in. Mobe to location. PTW and JSA. Spot and rig up lubricator. PT lubricator to 250 psi low and 2,500 psi high. Well flow 149K at 48 psi. RIH w/GPT and tied into OHL. Found fluid level at 6,183'. Showed flow in T17A and not much gas coming from T-18 Lower. Send log to town. POOH. RIH w/2.5" x 5' bailer down to 6,200' and catch fluid sample. POOH. Will send fluid sample to Baker Petro. Put today's date,T-17A and T-18 Lower arm perf gun. RIH w/2-7/8" x 17' Razor HC, 6 spf, 60 deg phase to 1,100'. Got call from town to pull out of hole due to change of plans. POOH. Rig down lubricator and equipment. Turn well back over to field. • 0 Ninilchik Unit • II Kalotsa #3 SCHEMATIC PTD: 217-028 API: 50-133-20661-00 Hilcorp Alaska,LLC RKB to GL=19.1' CASING DETAIL 16" 4 x Size Type Wt Grade Conn. ID Top Btm Conductor-Driven #.. # `' 16" 84 X-56 Weld 15.01" Surf 120' to Set Depth 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,418' r 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' i JEWELRY DETAIL ""; .4 No. Depth ID OD Item ' 1 1,280' 3.958" 6.875" Swell Packer } 2 6,881' 3.375" Permanent Patch 6,881'-6,903'11/06/17 3 8,760' 3.958" CIBP w/10'of cement 10/22/17 ° Te x 4 8,950' 3.958" CIBP w/25'cement 10/12/17 7.7.'ill � I 5 9,012' 3.958" CIBP w/5'of cement 9/10/17 .gip rr- If it �i` 7 5/8 • x r PERFORATION DETAIL " ' Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Date Status 1, „ n 6,249' 6,259' 5,246' 5,229' 10 11/06/17 Open T17A 6,259' 6,265' 6 12/14/17 Open 6,270' 6,285' 15 12/14/17 Open °" . _ . ; T18 6,418' 6,433' 15 02/07/18 Open 4liti ,..4,,,,,lit T43 6,887' 6,899' 5,844' 5,855' 12 10/21/17 Isolated T142 8,767' 8,777' 10 10/13/17 Open 6-3/4" (..:,.r. T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated c .„--.4. �,_+ Hole «;r T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated RA @ 3,987 0,4,,, ,s- r .0 RA @ 5,438' it 4,4, w alt....."alt....."> T17A s w RA @ 6,474' T ' •• ";a ..:R; T18 x-I,x °,. ,, T43 3.80"(3.375" ID)X 21'Owens Tubing Patch " °! 2 F/6,881'-6,903'. RA @ 7,470' t' TOC @8,750 i, ' .., T142 10/21/17 . r 3 TOC @ 8,950 h ""4' 10/12/1 #, ter4 .- a. TOC@9,007 .:,,4p`� �litaffiiiiirli. T146 OPEN HOLE/CEMENT DETAIL 09/10/17 " " 9-7/8"hole.84 BBL(200 sx)of 12 ppg Class A lead and 36 BBLs(155sx)15.4 ppg ` _ _ iii $ 7 5/8 Class G tail. 100%returns throughout,30 bbls to surface. 1147 6-3/4"hole.240 BBL(675 sx)12.5 Type I-II cement,followed with 32 BBL(160sx)of „tirtM 4-1/2" Class G tail.Lost 63 bbls during job,3 bbls of spacer returned to surface. 4 1/2" s&, PBTD=8,750'/PBTVD=7,660' TD=9,265'/TVD=8,173' Updated by DMA 11-03-17 THE STATE °fALASKA GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 3 Permit to Drill Number: 217-028 Sundry Number: 318-006 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French {\ Chair DATED this 1 day of January, 2018. RBDMS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JAN 0 5 2018 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Aker Casing ❑ ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q . Stratigraphic ❑ Service ❑ 217-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20661-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701A Will planned perforations require a spacing exception? Yes ❑ No ❑ Kalotsa 3 - 9. Property Designation (Lease Number): 10. Field/Pool(s): C061505 SHL / ADL359242 / ADL384372 TPH/BHL Ninilchik Field - Beluga/Tyonek Gas Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,265' 8,173' 9,007' 7,916' 2,138 psi 9,007' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 12U 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Por; N/A 1,280' MD/1,203' TVD; N/A 12. Attachments: Proposal Summary M Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� • Service ❑ 14. Estimated Data for 15. Well Status after proposed work: January 17, 2018 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramertidhilcorp.com Contact Phone: 777-8420 Authorized Signature: Date: COM IS ION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: YO -4/04 0 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: t tD rp\ ' s ,y- 8 /o �( Submit Form and Form 10-003 Revised 4/2017 (/ Approved application is va o��, tiii s r ri F�a e�of approval. �/ Attachmen in Duplicate /D�y i7 1-gljr, n ffilmm Alaska, LL, Well Prognosis Well: Kalotsa #3 Date: 1/2/2018 Well Name: Kalotsa #3 API Number: 50-133-20661-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: January 17, 2018 Rig: E -Line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: 17106320 12' Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary — 2,375 psi @ 5,431' TVD — 2,138 psi @ 5,431' TVD (Based on normal gradient of 0.437 psi/ft and the lowest proposed perforation) (Based on expected BHP and gas gradient to surface (0.10psi/ft) Kalotsa #3 is a development well targeting gas sands in the Tyonek formation. This well was drilled in June 2017. The Tyonek T -17A sand is currently open in the well. Adding the T-18 to this well will add rate to this well and help lift any water that is currently in the well bore. Notes Regarding Wellbore Condition • T -17A Sand is currently open and producing 150 mcfd. E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. 2. PU RIH With GPT tool and identify current fluid level in the well. 3. PU RIH With a bailer and collect a fluid Sample. 4. Perforate the Tyonek T-18 sand with 2-7/8" 6 SPF 60 deg phased pert guns (up to 12 SPF with 2 perf runs). Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Tyonek - ±6,388' ±6,408' ±5,415' ±5,431' 20' Upper Tyonek ±6,421 ±6,433 ±5,442' ±5452' 12' Lower a. Proposed perfs also shown on the proposed schematic in red font. b. T18 Lower perfs will be added separately from the T18 Upper Perfs. If these perk prove wet and add water to the gas stream, then a plug or a patch may be set to isolate water prior to perforating the T18 Upper Perfs. c. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. e. Use Gammal= to correlate. Well Prognosis Well: Kalotsa #3 Mears Alaska' LU Date: 1/2/2018 f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. Rule 2 of Conservation Order 701A defines the Ninilchik BelugalTyonek Gas Pool as the intervals common to and correlating between the measured depths of j,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 5. POOH. 6. RD a -line. 7. Turn well over to production. Attachments: Actual and Proposed Well Schematics Well Head Schematic 26„ B Hilemp Aleck", LLC RKB to GL =19.1' r) ' 6-3/4„ i. . Hole RA@3,987' - 14 RA@5,438' '&� ". 4 4. Kv ., RA@6,474' -A• n RA @ 7,470' w Toc@8,75a h, 10/22/v _ sr T17A SCHEMATIC CASING DETAIL Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 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 Cs 29.7 L-80 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 6,881' 3.375" Permanent Patch 6,881'-6,903' 11/06/17 3 8,760' 3.958" CIBP w/ 10' of cement 10/22/17 4 9,012' 3.958" CIBP w/5'of cement 9/10/17 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T17A 6,249'6,259' 5,246' 5,229' 10 11/06/17 Open T43 6,887' 6,899' 5,844' 5,855' 1 12 1 10/22/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated T43 3.80" (3.375" ID) X 21' Owens 2 Tubing Patch F/6,881' - 6,903'. i• 3 T146 L. - 9,00]' t . . 17 - f. _ 4 T147 s 4-1/2"� PBTD = 8,750'/ PBTVD = 7,660' TD=9,265'/TVD =8,173' OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBIs (155sx) 15.4 ppg Class G tail. 300% returns throughout, 30 bbls to surface. 4-112" 6-3/4" hole. 240 BBL (675 sx)12,5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls duringjob, 3 bbls of spacer returned to surface. Updated by DMA 11-03-17 tlikn.p,Uuxko, LLC RKB to GL=19.1' 16„ 7 -5/8 6-3/4' Hoc, RA @ 3,987' RA@5,438' �• a RA @ 6,474'~ e a T RA @ 7,470'it Toc La 8a5VIp Y.} PROPOSED SCHEMATIC T17A 4T43 r -, 2 3 9,00)' T146 0/10/ .- os/to/t7 -- 4 T147 PBTD = 8,750'/ PBTVD = 7,660' TD = 9,265'/ TVD = 8,173' CASING DETAIL Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 Size Type Wt I 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 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DFTAII No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 6,881' 3.375" 6,259' Permanent Patch 6,881'-6,903'11/06/17 3 8,760' 3.958" CIBP w/ 10' of cement 10/22/17 4 9,012' 3.958" CIBP w/ 5' of cement 9/10/17 PFRFnRATinN DFTAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status T17A 6,249' 6,259' 5,246' 5,229' 10 11/06/17 Open T18 ±6,388' ±6,408' ±5,415' ±5,431' 20 Pending TBD T18 ±6,421' ±6,433' ±5,442' ±5,452' 12 Pendin TBD T43 6,887' 6,899' 5,844' 5,855' 12 10/22/17 Isolated T146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Isolated T147 9,022' 9,033' 7,931' 7,942' it 07/27/17 Isolated OPEN HOLE/ CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx)15,4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-112" 6-3/4" hole. 240 BBL (675 sx) 12.5 Type 1 -II cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by DMA 11-03-17 Tubing head, C HP5, 13 5/8 SN 2-21/16 Starting head, 1 13 5/8 5M x 36 1/16 Sh Ninitchik Unit 16x]5/8 x4 BHTA, Otis, 41/16 5M FE x 6.5 Otis quick union top Ninilchik Unit Kalotsa #3 and #4 10/30/2017 Casing hanger, CW, 11 x 4 % D WC/C box btm x 6.125" RH stub acme box top.'a'/ 15/8 od neck, 4" type H BPV profile DD -NL material , WKM-M, 5" Hydraulic )r 21 7028 RECEIVED r JUL 19 2017 _ AOGCC Kallotsa 3 50-133-20661-00-00 Ninilchik Field Kenai Peninsula Borough, Alaska June 8, 2017 — June 26, 2017 Provided by: CANRIG , Approved by: Jacob Dunston Distribution Date: July 15, 2017 28420 Compiled by: Ralph Winkelman Eric Andrews Kalotsa 3 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW................................................................................................3 1.1 Equipment Summary., .................................................................................................................... 3 1.2 Crew................................................................................................................................................ 3 2 GENERAL WELL DETAILS...................................................................................................................4 2.1 Well Objectives...............................................................................................................................4 2.2 Hole Data........................................................................................................................................5 2.3 Daily Activity Summary ...................................................................................................................6 3 GEOLOGICAL DATA............................................................................................................................. 8 3.1 Lithostratigraphy.............................................................................................................................8 3.2 Lithology Details............................................................................................................................. 9 3.3 Sampling Program........................................................................................................................23 4 DRILLING DATA..................................................................................................................................24 4.1 Surveys.........................................................................................................................................24 4.2 Bit Record.....................................................................................................................................28 4.3 Mud Record..................................................................................................................................29 4.4. Drilling Progress...........................................................................................................................30 5 SHOW REPORTS...............................................................................................................................31 6 DAILY REPORTS................................................................................................................................32 Enclosures 2" / 100' Formation Log (MD/TVD) 5" / 100' Formation Log (MD/TVD) 2" / 100' LWD Combo Log (MD/TVD) 2" / 100' Drilling Dynamics Log (MD/TVD) 2" / 100' Gas Ratio Log (MD/TVD) Final Data CD CANRIG 2 J Kalotsa 3 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary 1.2 Crew Mud Logging Unit Type: Arctic Mud Loqqinq Unit Number: ML038 1-9giginp Geologists Years' Total Sample Catchers/Loggers Years Days 2 Parameter Equipment Type /Position Downtime Comments Computers—Surface Logging Rigwatch Server, gwatch 14 Leigh Ann Rasher 6 16 (3) Remote DML,LWD'WITS, 0 Eric Andrews Ri watch Remote 14 Ditch gas QGM gas trap; Flame ionization total gas & chromatography. Hook Load / Weight on bit WITS from Pason Mud Flow In Calculated value derived from 0 Strokes/Minute and Pum Output Mud Flow Out WITS from Pason " Pit Volumes, Pit Gain/Loss WITS from Pason " Pump Pressure WITS from Pason " Pump Stroke Counters 2 WITS from Pason " Rate of Penetration Calculated from Pason " RPM WITS from Pason " Tor ueWITS from Pason " WITS To/ From Pason Ri watch Remote HP Compaq) 1.2 Crew Mud Logging Unit Type: Arctic Mud Loqqinq Unit Number: ML038 1-9giginp Geologists Years' Da sZ Sample Catchers/Loggers Years Days 2 Ralph Winkelman 27 14 Leigh Ann Rasher 6 16 Marquel Mosebay 18 17 Eric Andrews 5 14 Years' experience as Mudlogger .2 Days at wellsite between rig up and rig down of logging unit. if Kalotsa 3 2 GENERAL WELL DETAILS 2.1 WellObiiectives Kalotsa #3 is an S-shaped directional grassroots development well to be drilled off of the Kalotsa pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development of the Upper Tyonek sands, as well as an area with little to no production in the Middle and Upper Beluga sands. The base plan is a directional wellbore with a kickoff point at 300' MD. Maximum hole angle will be 340 . TD of the well will be 8900' MD/ 7808' TVD, ending at 70 inclination. The vertical section will be 3880'. Operator: HILCORP ALASKA, LLC Well Name: Kalotsa 3 Field: Ninilchik Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Rance Pederson, Robert Wall , Clint Montague, Adam Dorr Location: Surface Coordinates 2262' FSL, 458' FWL, Sec 7, T1N, R13W, SM, AK Ground ( Pad ) Elevation 126.5' AMSL Rotary Table Elevation 18' RKB — 144.5' AMSL Classification: Development — Gas API #: 50-133-20661-00-00 Permit #: 217-028 Rig Name/Type: Saxon 169 / Land / Double Spud Date June 8, 2017 Total Depth Date: June 20, 2017 Total Depth 9265' MD Primary Targets Tyonek 65 7539'MD/ 6460'TVD, Tyonek 83 7848'MD/ 6764'TVD, Tyonek 90 8006'MD/ 6921'TVD Total Depth Formation: Tyonek Completion Status: 4 1/2" Casing LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service Schlumberger J_ Kalotsa 3 2.2 Hole Data Hole Section Max Depth TD Formation MW PP9 Dev 'inc Csg Dia Shoe Depth LOT MD TVD ft ft MD ft TVD ft 9 7/8" 1423' 1319.37' Beluga 9.10 34.90 75/8 1419' 1316.7' 14.26 6'/<" 9265' 8173' Tyonek 9.8 3.58 4'/2' 9254' 8162' NA CANRIG Kalotsa 3 2.3 Daily Activity Summary June 8, 2017: Rig up mudlogging unit June 8, 2017: Completed rig up, picked up drill pipe, serviced Rig, picked up bit and mud motor, and ran into the hole to tag 125'. Drilled a rat hole from 125' to 250', pulled out of the hole, laid down dumb iron, and picked up smart tools. Ran back into the hole to 250' and drilled ahead to 1025'. June 9, 2017: Drilled ahead from 1025' to 1423', pumped sweep, circulated hole clean, and pulled out of the hole. Laid down tools, serviced rig, made up float and test float equipment. Ran in hole with 7 5/8" casing from 123' to 1412', circulated mud, rigged down casing equipment, rigged up cementing equipment. Performed Cementjob and began rigging down cement equipment. June 10, 2017: Completed rigging down cement equipment, prepared rig for upcoming BOP test, and began picking up and racking back drill pipe. June 11, 2017: Perform BOP test, make up BHA, pick up Drill pipe, and run into hole to 756'. June 12, 2017: Continued running into the hole from 756' to shoe at 1412' and re -drilled the rat hole to 1423' plus 20' of new formation at 1443'. Circulated bottoms up, displaced mud system, performed FIT test, and drilled ahead from 1443' to 2468'. Circulated mud and pulled out of the hole from 2468' to 1409' for a wiper trip. Serviced rig and ran back into the hole from 1409' to 2468' and drilled ahead to 2715'. June 13, 2017: Continued drilling from 2715' to 3465', picked up, circulated sweep, and pulled out of the hole from 3465' to 2406' for wiper trip. Serviced rig and ran back into the hole from 2406' to 3465'. Continued drilling from 3495' to 4335', pumping sweeps when needed. June 14, 2017: Continue drilling ahead from 4335' to 4458', pick up, circulate, pump sweep and pull out of hole from 4458' to 1410' for wiper trip. Service rig and run back into hole from 1410' to 4458'. Drill ahead from 4458' to 5452', circulate, pump sweep, and prepare to pull out of hole for wiper trip. June 15, 2017: Pulled out of the hole from 5452' to 4397', serviced rig, and ran back into the hole from 4397' to 5452'. Drilled ahead from 5452' to 6450', pumping sweeps when needed. Picked up, circulated, pumped a sweep, and pulled out of the hole from 6450' to 5445' for a wiper trip. June 16, 2017: Ran back into the hole from 5445' to 6450', circulated, and drilled ahead to 7448'. Circulated at 7448', pumped sweep, and pulled out of hole to 6391' for a wiper trip. Ran back into the hole from 6391' to 7448' and drill ahead to 7500'. June 17, 2017: Drilled ahead from 7500' to 7575', trouble shoot MWD tools, and continued drilling from 7575' to 7824'. Decided to pull out of the hole to change MWD tools. Picked up, Circulated, and pulled out of the hole from 7824' to 4224'. Due to swabbing with high gas we ran back into the hole from 4224' to 7824', circulated, weighted up mud, and prepared to pull back out of the hole. June 18, 2017: Pulled out of the hole from 7824' to surface, removed sources, and downloaded tool. Picked up new motor, bit, and MWD tool. Downloaded MWD tools and performed a shallow pulse test. Made up BHA and ran into the hole to 4830'. June 19, 2017: Continued running into the hole from 4830' to 7824'. Drilled ahead to from 7824' to 8783' circulating and pumping sweeps when needed. CANRIG J_ Kalotsa 3 June 20, 2017: Continue to drill head to TD at 9265', Circulate sweep, Wipe hole to 7515', back ream as needed, Circulate bottoms up, max gas of 146u, Trip in the hole to 9260', Circulate bottoms up, max gas of 394u, POOH from 9260', pump out of hole from 9260' to 8945', Flow check, Continue to POOH to pick up Schlumberger logging tools. June 21, 2017: Continue to pull out of hole and lay down BHA. Make up clean out BHA, hold PJSM with Schlumberger loggers and rig up wire line drift log tool. Run in hole and hit tight spot at 4870'. Rig down drift tool and rig up XPT tool. Run in hole with XPT tool and out of hole with XPT tool, tool not getting readings. Lay down XPT and pick up new XPT tool. Run in hole with XPT tool and hit bridge at 4870'. Wireline from 8900' to 4320'. Service rig and continue with XPT Wireline operations from 4320'. June 22, 2017: Continue with Wireline operations from 4320' to 2378'. Service rig, monitor well and finish up the XPT wireline run. Lay down XPT tool and pick up SWC tool. Run in hole and hit bridge at 6480'. Start coring from 6426' to 1560'. Service rig, pull out of hole and lay down SWC tool. Run in hole with triple combo tool to 6480'. June 23, 2017: Continue logging with triple combo tool from 6480'. Service rig and pull out of hole with tool. Lay down hanger and RA sources, pick up SWC tool and run in the hole with SWC. Lay down SWC tool because tool jammed up again. Lay down SWC tool, pick up PNX tool and run in hole to bridge out at 6480'. Log from 6480' to 5828'. June 24, 2017: Continue logging PNX from 5828' to 1419'. Pull out of hole from 1419' to surface and lay down logging tools. Rig down Schlumberger logging equipment and service rig. Pick up clean out BHA and run in hole to 1307'. Fill pipe and circulate bottoms up with a max gas of 8 units. Slip and cut 120' of drill line and continue to run in hole from 1307' to 3241', filling pipe every 15 stands. Circulate at 3241', max Gas 36 units, stage in hole, circulate bottoms up at 6352', max gas 808 units, circulate bottoms up at 8784', max gas 1435 units, circulate bottoms up at 8998', max gas 3491 units. Continue to run in hole to bottom, circulate sweep at 9265'. Circulate clean, rack back 5 stands in Derrick, flow check, pump dry job at 8904' and pull out of hole laying down drill pipe from 8904' to 5277'. June 25, 2017: Pull out of hole and lay down drill pipe from 5277'. Continue laying down drill pipe from 5277' to 4586', pulled 40K over, reamed tight spot at 4586' and circulate bottoms up. Continue laying down drill pipe to 378', trip in hole from 378' to 944' and lay down drill pipe to 0'. Prepare for Shell BOPE test, BOPE test complete and pull test plug. Run hanger, rig up casing equipment and pick up and make up float equipment. Test float equipment and begin running in hole with 4.5" production casing to 2985'. June 25, 2017: Circulate at 2985', surface to surface, max gas 76 units. Monitor well and continue running in hole with 4.5" production casing string. Circulate bottoms up at 5553', max gas 81 units. Run in hole with casing from 5553' and land 4.5" casing at 9254' MD. Circulate and condition mud, max gas 328 units. Pump cement. Canrig mud loggers released and rig down unit. CANRIG Kalotsa 3 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Kalotsa 3 - Tops picked by Hilcoro Geologist, Jacob Dunston FORMATION PROGNOSED ACTUAL MD ft TVD ft SSTVD ft MD ft TVD ft SSTVD ft Primary T65 7539 6460 -6315 7,624 6,543 -6,398 T83 7848 6764 -6619 7,902 6,818 -6,673 T90 8006 6921 -6776 8,064 6,978 -6,833 Secondary T3 4465 3831 -3686 4,480 3,826 -3,681 T6 4777 4089 -3944 4,802 4,092 -3,947 T140 8562 7473 -7328 8,603 7,514 -7,369 CANRIG rfJ- Kalotsa 3 3.2 Litholoav Details As per Hilcorp direction, a Canrig/NDS-provided full service mudlogging program, with lithology descriptions of interval -collected rock cuttings samples in the Beluga and Tyonek Formations, was initiated at the 6 W production interval at 1423'. The Kenai Group formations of Alaska's Cook Inlet Basin, which include the Sterling, Beluga, and Tyonek were deposited in a variable -energy fluvial system within a large closed fore -arc basin. The stratigraphic column consists of very dominant thin to massive sections of sandstone and claystone-siltstone, which are interrupted by extensively -distributed thinner zones of coal and carbonaceous rocks, locally to generally abundant thin layers of original and re -deposited volcanic ash, and minor beds of basal or modal conglomerate. Gradational upward -fining sequences and bi-modal zones are abundant within the sandstones. Stratovolcanoes, perpetually forming along the fore -arc's margins; produced abundant widely -distributed deposits of vitric air fall volcanic ash; which became a major directly -derived source, and/or a consistent lithogenic influence, for all Tertiary soft -sediment rocks in the Cook Inlet Basin. Note that the special modifying term "tuffaceous' in Canrig/NDS Lithology Descriptions was created to address the diversity of volcanic -origin rocks in the Cook Inlet basin, and its use may include everything from discernible micro -shard concentrations of disaggregated volcanic glass to rare layers of vitric ignimbrite. Coal/ Carbonaceous Shale (1423'- 1440) = black to brownish black; hard to moderately hard; pdc bit aggregated; sharp, bladed cuttings; dull luster; smooth to slightly abrasive textures; thin structure; weak to moderate outgassing. Sand (1460'- 1530') = dark gray to grayish black with medium dark gray secondary hues; quartz and feldspar framework; upper fine to lower medium sand grains, occasionally upper medium; poor to moderately sorted; subangular to subrounded; moderate to very high sphericity; unconsolidated; trace thin coal beds; common carbonaceous materials present; abundant hard gray lith; trace green, yellow, grayish pink, and orange lith; trace mica. Tuffaceous Claystone (1630'- 1590') = dark gray to medium dark gray with medium gray secondary hues; expansive clay properties, stiff consistency; brittle to crumbly tenacity; earthy fracture; tabular to wedgelike cuttings habit; greasy, earthy luster; smooth and clayey to slightly silty texture; trace carbonaceous material; non calcareous. Sand (1600'- 1650') = dark gray to grayish black with medium dark gray and black secondary hues; quartz and feldspar framework; lower very fine to upper fine sand grains; poor to moderately sorted; subangular to subrounded, occasionally rounded; moderate to high sphericity; unconsolidated sand grains; abundant gray lith; trace carbonaceous material. Tuffaceous Claystone (1650' -1700') = medium dark gray to dark gray; expansive clay properties; stiff to slimy consistency; brittle to crumbly tenacity; earthy fracture; tabular to wedgelike cuttings habit; greasy, earthy luster; smooth, clayey to slightly granular texture; trace carbonaceous microthin laminae, trace suspended carbonaceous fragments; trace mica; non calcareous. Coal/ Carbonaceous Shale (1700' -1770) = black with brownish black and grayish black secondary hues; very firm to hard and brittle; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster; moderately well developed; sub bituminous; occasionally grading to carbonaceous shale; trace to common outgassing bubbles observed; present as thin beds in dominantly claystone formation. [�'�► Vie_' Kalotsa 3 Tuffaceous Claystone/ Tuffaceous Siltstone (1770' -1840') = medium light gray to light gray with very light gray secondary hues; soft to slightly firm; sticky at times; irregular, shapeless to trace wedge shaped cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; moderate to very soluble and expansive; poor adhesiveness; poor to fair cohesiveness; non calcareous, trace dark brown to black microthin carbonaceous laminations and inclusions; trace to common thin coal beds throughout interval. Sand (1840' - 1900') = medium gray overall with a strong salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black; very fine upper to medium upper, dominantly fine; angular to subangular; moderately well sorted; unconsolidated; slight to moderately calcareous overall; trace to common thin coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (1900'- 1970') = medium light gray to light gray with very light gray secondary hues; soft to slightly firm; sticky at times; irregular, shapeless to trace wedge shaped cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; moderate to very soluble and expansive; poor adhesiveness; poor to fair cohesiveness; non calcareous, trace to common thin coal beds throughout interval; no to trace outgassing bubbles observed. Coal/ Carbonaceous Shale (1970'- 2030') = black with brownish black and grayish black secondary hues; very firm to hard and brittle; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster, moderately well developed; sub bituminous; occasionally grading to carbonaceous shale; no to weak trace outgassing. Sand (2030'- 2090') = medium to medium dark gray with weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to medium upper, dominantly fine upper to medium lower; angular to subangular; moderately well sorted; disaggregated; non to trace calcareous; trace to common thin coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (2090' - 2150') = medium gray to medium light gray with very light brown to very light brownish gray secondary hues, very soft; irregular to shapeless; silty to clayey texture; dull luster; hydrophilic; moderate to very soluble and expansive; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace to common thin coal beds throughout interval; no to weak trace outgassing. Sand (2150' - 2210) = medium gray overall with a strong salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black; very fine upper to medium upper, dominantly fine; angular to subangular; moderately well sorted; unconsolidated; non to slightly calcareous overall; trace to common thin coal beds throughout interval, no outgassing bubbles observed. Coal/ Carbonaceous Shale (2210'- 2270') = black with brownish black and grayish black secondary hues; very firm to hard and brittle; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to matte texture, resinous to slightly earthy luster; poor to fair development; subbituminous to bituminous; commonly grading to carbonaceous shale, no outgassing bubbles observed; present as very thin beds in dominantly claystone formation. Tuffaceous Claystone/ Tuffaceous Siltstone (2270' - 2340') = medium light gray to light gray with very light gray secondary hues; soft to slightly firm; very silty; irregular, shapeless to trace wedge shaped cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; moderate to very soluble and expansive; poor adhesiveness; poor to fair cohesiveness, non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. 10 CANRIG .i Kalotsa 3 Tuffaceous Claystone/ Tuffaceous Siltstone (2340' - 2400') = medium gray to medium light gray with very light brown to very light brownish gray secondary hues; very soft; irregular to shapeless; silty to clayey texture; dull luster; hydrophilic; moderate to very soluble and expansive; poor to fair cohesiveness poor adhesiveness; non calcareous; trace to common thin coal beds throughout interval; no outgassing bubbles; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (2400' - 2460') = medium to medium dark gray with weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to medium upper, dominantly fine upper to medium lower; angular to subangular; moderately well sorted disaggregated; non calcareous. Sand (2460' - 2530') = medium dark gray to dark gray with grayish black secondary hues; dominantly grey lithics framework, secondary clear and opaque quartz and feldspar; upper fine to upper medium sand grains; moderately sorted; angular to subangular; low to moderate sphericity; unconsolidated; trace thin coals throughout interval; trace carbonaceous material; trace mica; trace reddish pink, dark yellow, white lith; no reaction to 10% hcl in sample. Tuffaceous Claystone (2530'- 2580') = medium gray to medium dark gray with dark gray secondary hues; expansive clay properties, occasionally adhesive; stiff consistency; brittle to crumbly, sometimes sectile; earthy fracture; platy to tabular and wedgelike cuttings habit; greasy to dull luster; smooth, clayey texture, thin coal beds throughout interval; non calcareous; moderate outgassing observed from coal. Tuffaceous Claystone (2580'- 2650) = medium dark gray to dark gray with medium gray secondary hues; stiff to slightly mushy tenacity; earthy fracture; tabular to platy to globular and shapeless cuttings habit; dull, earthy luster; smooth, clayey to silty and slightly gritty texture with suspended black carbonaceous fragments; thin coal beds throughout interval, trace hard sandstone; non calcareous. Tuffaceous Claystone (2650'- 2700') = medium dark gray to dark gray; adhesive and expansive clay properties; stiff to mushy tenacity; earthy fracture; tabular to wedgelike and often shapeless cuttings habit; greasy to dull luster; clayey to silty texture; trace black suspended fragments; non calcareous. Coal (2740' - 2770') = black to brownish black; pdc bit disaggregated; brittle to crumbly; splintery to hackly fracture; flaky, platy, wedgelike, bladed cuttings habit; resinous to dull luster; matte to abrasive texture; thin structure, bedded in claystone; moderate outgassing. Tuffaceous Claystone (2770'- 2520) = dark gray to medium dark gray with grayish black secondary hues; adhesive clay properties, stiff consistency; brittle to crumbly and pulverulent tenacity, occasionally sectile; earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; smooth, clayey texture to slightly silty; bedded with sand and thin coals throughout interval; non calcareous. Sand (2810'- 2860') = dark gray to medium dark gray; weak salt and pepper appearance; medium dark gray lithics and felsic framework; upper very fine to upper fine grains; moderately sorted; subrounded to round, trace subangular; moderate to high sphericity; unconsolidated, trace carbonaceous material; no reaction to 10% hcl in sample. Sand (2880' - 2940') = dark gray to grayish black with a medium dark gray secondary hue; framework is dominantly dark gray lithics, translucenttclear and opaque quartz and feldspar are both very abundant; lower very fine to upper fine grains; moderate to well sorted; subrounded to rounded, rarely angular to subangular; moderate to high sphericity; unconsolidated; trace carbonaceous material; trace mica; trace thin to microthin coal beds throughout interval; non calcareous. 11 CANRIG J . Kalotsa 3 Coal (2960'- 2970') = black to grayish black and brownish black; hard and brittle to moderately hard and crumbly tenacity; hackly, splintery, planar, and sometimes blocky fracture; pdc bit disaggregated; platy and flaky to wedgelike with bladed edges; resinous luster; abrasive to matte texture with occasional smooth faces; thin structure; moderate to heavy outgassing. Tuffaceous Claystone (3000' - 3050') = medium dark gray to dark gray with olive gray and brownish gray secondary hues; weak adhesive clay properties; expansive; earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; clayey to slightly silty texture; thin to microthin coals common; trace sandstone; trace carbonaceous fragments often suspended in claystone; trace tuff; non calcareous. Sand (3060' - 3120') = dark gray to grayish black with medium dark gray secondary hues; dominantly clear to opaque quartz and feldspar framework; lower very fine to upper fine grains; moderate to well sorted; subrounded to rounded, common subangular; moderate to high sphericity; unconsolidated; trace carbonaceous fragments; trace microthin to thin coals throughout interval; non calcareous. Sandstone (3120' - 3170') = medium dark gray to dark gray; dark gray lithic framework; very fine to fine; very well sorted; subangular; moderate to high sphericity; very hard; calcite cement material; grain support; sutured to concave fabric; thin bedding; trace carbonaceous material; common quartz and feldspar; strong reaction to 10% hcl. Tuffaceous Claystone (3180'- 3230') = medium dark gray to dark gray; moderately adhesive clay properties; adhesive; stiff to slightly pasty consistency; brittle to crumbly and sectile; earthy fracture; tabular to wedgelike and often shapeless cuttings habit; greasy to dull luster; smooth, clayey texture; trace carbonaceous fragments; non calcareous; common microthin to thin coals throughout interval; moderate outgassing. Sand/ Sandstone (3230'- 3300') = medium dark gray to dark gray with olive gray secondary hues; upper very fine to upper fine grains; well to very well sorted; subangular to subrounded; moderate to high sphericity; unconsolidated; trace carbonaceous material; common gray hard lithics; sandstone; gray lithics framework; very fine to fine grained; moderate to well sorted; subrounded; moderate to high sphericity; moderately hard to very hard; calcite cement; grain support; concave/convex support; trace suspended carbonaceous material. Tuffaceous Claystone (3300' - 3380') = medium dark gray to dark gray with olive gray secondary hues; cohesive and adhesive clay properties; expansive; dominantly mushy to pasty, trace stiff consistency; malleable to sectile tenacity; earthy fracture; dominantly globular and shapeless, trace tabular to wedgelike cuttings habit; dull to greasy luster; smooth to silty texture, often granular with suspended lith; trace carbonaceous material; non calcareous; trace thin coal beds throughout interval; moderate to heavy outgassing. Coal/ Carbonaceous Shale (3380'- 3460') = black with brownish black secondary hues; hard; brittle at times; blocky to platy; massive; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly silty texture; resinous to slightly earthy luster; very well developed; bituminous with scattered, less developed carbonaceous shale; vigorous and prolonged outgassing bubbles present Sand (3460'- 3520') = medium gray to medium light gray with weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and black; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; unconsolidated; non calcareous; trace thin coal beds throughout interval. 12 CANRIG J- Kalotsa 3 Tuffaceous Claystone/ Tuffaceous Siltstone (3520' - 3580') = medium light gray to light gray; very soft; sticky at times; shapeless, globular cuttings; silty to clayey texture; dull to earthy slimy to pasty; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; poor to fair adhesiveness; non calcareous; trace to common thin coal beds throughout. Coal/ Carbonaceous Shale (3880'- 3640') = black with brownish black secondary hues; hard; brittle at times; blocky to platy; massive; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly silty texture; resinous to slightly earthy luster; very well developed; bituminous with scattered, less developed carbonaceous shale; no to trace weak outgassing bubbles observed; coal present as thin beds in dominantly claystone formation. Tuffaceous Claystone/ Tuffaceous Siltstone (3640'- 3700) = medium light gray to light gray; very soft; sticky at times; shapeless, globular cuttings; silty to clayey texture; dull to earthy luster; slimy; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; common to abundant coal beds throughout; trace outgassing bubbles observed. Sand (3700' - 3760') = medium gray to medium light gray with salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and dark gray black; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; unconsolidated; non calcareous; trace to common coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (3760' - 3830') = medium light gray to light gray with very light gray secondary hues; very soft; shapeless, globular, amorphous cuttings; silty to clayey texture; dull to greasy luster; slimy to pasty; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; poor to fair adhesiveness, non calcareous, trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments, common to abundant coal beds throughout. Tuffaceous Claystone/ Tuffaceous Siltstone (3830' - 3900') = medium light gray to light gray; very soft; sticky at times; shapeless, globular cuttings; silty to clayey texture; dull to earthy luster; slimy; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; common to abundant coal beds throughout; trace dark brown to black microthin carbonaceous laminations and inclusions in firm fragments. Tuffaceous Claystone/ Tuffaceous Siltstone (3900'- 3960') = medium light gray to light gray with trace dark gray secondary hues; very soft; shapeless, globular, amorphous cuttings; silty to clayey texture; dull to greasy luster; slimy to pasty; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; poor to fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in trace firmer fragments. Sand (3960' - 4020') = medium light to light gray overall with individual grain dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated; trace salt and pepper sandstone; hard; fine to medium; moderate to strong calcareous cement; trace thin coal beds. Tuffaceous Siltstone (4020'- 4070') = medium gray to medium gray with brownish gray and olive gray secondary hues; expansive; stiff consistency; brittle to crumbly, sometimes pulverulent tenacity; tabular to wedgelike and platy cuttings habit; dull, earthy luster; silty to slightly gritty texture; trace microthin black to brownish black carbonaceous laminations and suspended fragments; no reaction to 10% hcl in sample. 13 CANRIG Kalotsa 3 Tuffaceous Sandstone (4080'- 4130) = medium gray to medium dark gray to dark gray with olive gray secondary hues; grey lithic and felsic framework; lower very fine to lower fine grains; well to very well sorted; subrounded; moderate to high sphericity; moderately hard to hard; calcite cement; tuffaceous matrix support; long contact, point contact, concavelconvex fabric; thin bedding; trace carbonaceous fragments; strong reaction to 10% hcl. Tuffaceous Claystone (4140'- 4190') = medium dark gray to dark gray with brownish gray and olive gray secondary hues; stiff tenacity; earthy fracture; pdc disaggregated; tabular to wedgelike and platy cuttings habit; dull, earthy luster; smooth to silty texture; trace carbonaceous microthin laminations, non calcareous. Sand/ Sandstone (4190' - 4260') = medium gray to medium dark gray with olive gray secondary hues; quartz and feldspar framework; lower very fine to upper find sand grains; moderate to well sorted; subangular to subrounded; moderate to high sphericity; unconsolidated; bedded dominantly siltstone and claystone; trace dark yellow, reddish pink, reddish orange, grayish purple, and pink lithics; sandstone; moderately hard to hard; fine grained; moderate to well sorted; subrounded; calcite cement, tuffaceous matrix; long contact fabric; trace carbonaceous material. Tuffaceous Claystone (4260'- 4320') = medium gray to medium dark gray with olive gray secondary hues; adhesive to plastic clay properties; expansive; pasty to mushy consistency; malleable to sectile tenacity; earthy fracture; globular to shapeless cuttings habit; greasy luster; smooth to silty and slightly gritty with suspended lithics; trace carbonaceous lithics; no reaction to 10% hcl. Tuffaceous Sandstone (4350'- 4410') = medium light gray to medium gray to medium dark gray; quartz and feldspar framework, upper very fine to upper fine grains; moderate to well sorting; subangular to subrounded; moderate to high sphericity, pdc disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix; point contact, long contact, and floating grain fabric; trace carbonaceous material; non calcareous. Sand (4410'- 4450) = medium dark gray to olive gray; moderate salt and pepper appearance; quartz and feldspar framework; lower very fine to lower fine grains; well sorted; subangular to sub rounded; moderate to high sphericity; unconsolidated; trace dark yellow, reddish orange lithics. Tuffaceous Claystone/ Tuffaceous Siltstone (4450'- 4530') = light gray with light brownish gray secondary hues; very soft; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; very soluble; poor cohesiveness; poor to fair adhesiveness; non calcareous; trace thin coal beds. Sand/ Sandstone/ Tuffaceous Sandstone (4530' - 4590') = light to very light gray with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to fine upper, dominantly fine lower; angular to subangular; well sorted; dominantly unconsolidated with trace salt and pepper sandstone; fine to medium; hard; very calcareous cement; scattered grayish white, ashy matrix supporting loose sand grains. Tuffaceous Claystone/ Tuffaceous Siltstone (4590'- 4640') = light gray with light brownish gray secondary hues; very soft; shapeless, globular cuttings, silty to clayey texture; dull to greasy luster; very soluble; poor cohesiveness; poor to fair adhesiveness; non calcareous; very light brownish gray siltstone grade between sandy siltstone and silty sandstone; soft; fragile. Sand (4640'- 4700') = very light gray with yellowish gray secondary hue overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to fine upper, dominantly fine lower; angular to subangular; very well sorted; disaggregated; sand is suspended in dominantly a clay formation; non calcareous 14 14 0 Kalotsa 3 Tuffaceous Claystone/ Tuffaceous Siltstone (4700' - 4770') = light gray to very light gray to light yellowish gray with very light brownish gray secondary hues; very soft; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; poor to fair adhesiveness; non calcareous; light yellowish gray siltstone commonly grades between sandy siltstone and silty sandstone; soft; fragile; non calcareous; trace very thin coal beds; no outgassing observed. Tuffaceous Claystone/ Tuffaceous Siltstone (4770' - 4830') = light gray with light yellowish gray secondary hues; very soft; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; very soluble; poor cohesiveness; poor to fair adhesiveness; non calcareous; very light brownish gray siltstone grade between sandy siltstone and silty sandstone; soft; fragile, trace coal beds; no outgassing bubbles observed. Sandstone/ Sand (4830' - 4890') = medium light gray with salt and pepper appearance; firm to hard; fine; angular to subangular; moderately well sorted; moderate to very calcareous cement; individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to fine upper, dominantly fine lower; angular to subangular; moderately well sorted; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (4890' - 4950') = very light yellowish gray to light brownish gray with medium gray secondary hues; very soft to occasionally firm; irregular to shapeless, globular cuttings; silty to clayey texture, dull luster; hydrophilic; poor adhesiveness and cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in rare firmer fragments. Sand (4950' - 5010') = very light gray to very light yellowish gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace darker liths; very fine lower to medium lower, dominantly fine upper; angular to subangular; very well sorted; disaggregated; sand is suspended in dominantly a clay formation; non calcareous; trace thin coal beds; no outgassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (5010' - 5080') = light gray to very light gray to light yellowish gray with very light brownish gray secondary hues; very soft; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; poor to fair adhesiveness; non calcareous; light yellowish gray siltstone commonly grades between sandy siltstone and silty sandstone; soft; fragile; non calcareous; trace black, microthin carbonaceous laminations. Tuffaceous Sandstone/ Sand/ Sandstone (5080' - 5410') = very light gray to grayish white; soft to fragile and pulverulent; moderate to very calcareous; ashy matrix acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium lower, dominantly fine, angular to subangular; moderately well sorted, trace salt and pepper sandstone; hard, brittle. Tuffaceous Claystone/ Tuffaceous Siltstone (5410'- 5210') = very light yellowish gray to light brownish gray with medium gray secondary hues; very soft to occasionally firm; irregular to shapeless, globular cuttings; silty to clayey texture; dull luster; hydrophilic; poor adhesiveness and cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in rare firmer fragments; trace thin coal beds; no outgassing bubbles. 15 r.UMr:7ra� J Kalotsa 3 Sand/ Sandstone (5210'- 5270') = medium dark gray to dark gray with olive gray and brownish gray secondary hues; clear to opaque quartz and feldspar framework; lower very fine to upper fine grains; moderate to well sorted; subangular to subrounded; high sphericity; unconsolidated; trace carbonaceous material; olive gray to gray sandstone; very fine grained; well sorted; subrounded; high sphericity; pdc disaggregated; moderately hard; clay mineral cement; grain support; long contact, concave/ convex fabric; thin bedding; trace suspended carbonaceous material; non calcareous. Tuffaceous Sandstone (6270'- 5350') = olive gray to brownish gray with medium gray and medium dark gray secondary hues; quartz and feldspar framework; lower very fine to lower fine sand grains; well to very well sorted; subrounded to rounded; moderate to high sphericity; pdc disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix; point contact, long contact, floating contact fabric; thin bedding; trace carbonaceous material; non calcareous. Sand (5350' - 5440') = medium light gray to medium gray to medium dark gray with olive gray secondary hues; moderate salt and pepper appearance; dominantly quartz and feldspar; lower very fine to upper fine grains; well sorted; subangular to subrounded; moderate to high sphericity; unconsolidated sand grains; trace carbonaceous material; trace thin to microthin coal; no outgassing; non calcareous. Tuffaceous Claystone (5440'- 5510') = medium dark gray to dark gray with olive gray and brownish gray secondary hues; plastic clay properties; stiff consistency; dense and brittle tenacity; earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; smooth, clayey to silty texture; thin structure; coal beds throughout interval; very weak outgassing observed. Sand (6520'- 5580') = medium dark gray to dark gray to olive gray; dominantly translucent to opaque quartz and feldspar framework; lower very fine to upper fine grains, common medium sand grains; moderate to well sorted; subangular to sub rounded; moderate to high sphericity; unconsolidated sand grains; trace to common carbonaceous material; trace pink, dark yellow, light yellow, orange, reddish orange lithics; common gray lithics; no reaction to hcl in sample. Sand/ Tuffaceous Sandstone/ Conglomerate (6580'- 5640') = medium light gray to medium gray with light olive gray hues; clear to translucent quartz and feldspar dominant; upper fine to upper coarse grains with 2mm pebbles; poor to moderately sorted; subangular to subrounded and angular; moderate to high sphericity; unconsolidated grains; trace pale yellow, reddish orange, green, pinkish red, grayish purple lithics; common gray lithics; trace tuff; tuffaceous sandstone pdc disaggregated; easily friable; clay mineral cement; very tuffaceous matrix; floating and point contact fabric; common carbonaceous material; non calcareous. Coal (5680' - 5710') = black to brownish black; pdc aggregated; crunchy to pulverulent; splintery, hackly fracture; flaky, scaly, bladed cuttings habit; dull, earthy, occasionally resinous luster; abrasive texture with trace smooth faces; thin structure, very weak to mild outgassing. Tuffaceous Siltstone/ Tuffaceous Claystone (5710'- 5790') = light gray to light brownish gray with light olive gray secondary hues; soft and fragile; irregular, rounded cuttings; silty to clayey to slightly gritty texture; dull to sparkly luster; soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace to common thin coal beds throughout interval. Sand (5790' - 5870') = light gray with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium lower; dominantly fine; angular to subangular; moderately well sorted; unconsolidated with trace ashy matrix supporting loose sand grains; grayish white; very fragile; non calcareous; common light yellowish gray sandstone; fragile; grades between silty sandstone and sandy siltstone; trace to common thin coal beds throughout interval; no outgassing bubbles observed. 16 'OMRIG Kalotsa 3 Tuffaceous Claystone/ Tuffaceous Siltstone (5870' - 5930') = very light yellowish gray to light brownish gray with medium gray secondary hues; very soft to occasionally firm; irregular to shapeless, globular cuttings; silty to clayey texture; dull luster; hydrophilic; poor adhesiveness and cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in rare firmer fragments; trace thin coal beds; no outgassing bubbles. Sandstone/ Sand (5930' - 6000') = light gray to medium light gray with salt and pepper appearance, hard and brittle to soft and mushy; fine to medium grain; angular to subangular; moderately well sorted; moderate to very calcareous cement; light brown to brownish gray sandstone; soft; very fine lower to upper; well sorted; grain supported; non calcareous; silty in part; commonly grades between sandy siltstone and silty sandstone; trace thin coal beds throughout interval; no outgassing observed. Tuffaceous Siltstone/ Tuffaceous Claystone (6000' - 6070') = light gray to light brownish gray with light olive gray secondary hues; soft and fragile; irregular, rounded cuttings; silty to clayey to slightly gritty texture; dull to sparkly luster; soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; soft, yellowish gray siltstone commonly grades between sandy siltstone and silty sandstone; fragile; non calcareous. Sand (6070' - 6140') = light gray with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium lower; dominantly fine; angular to subangular; moderately well sorted; unconsolidated with trace ashy matrix supporting loose sand grains; grayish white; very fragile; non calcareous; common light yellowish gray sandstone; fragile; grades between silty sandstone and sandy siltstone; trace thin coal beds. Tuffaceous Sandstone/ Sand (6140'- 6200') = very light gray to grayish white with abundant faint secondary hues; soft to fragile and pulverulent; irregular shaped; crunchy; non calcareous; ashy matrix supports loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well to well sorted; disaggregated with ash matrix common; non calcareous. Sand/ Conglomeratic Sand/ Tuffaceous Sandstone (6200'- 6260') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, white, black and dusky red; very fine to very coarse upper with pebble fragments 5mm, dominantly fine upper to medium upper; angular to subrounded, dominantly subangular; poorly sorted; disaggregated with ashy matrix common; very fragile. Tuffaceous Claystone/ Tuffaceous Siltstone (6260' - 6330') = very light yellowish gray to light brownish gray with medium gray secondary hues; very soft to occasionally firm; irregular to shapeless, globular cuttings; silty to clayey texture; dull luster, hydrophilic; poor adhesiveness and cohesiveness; non calcareous; light yellowish gray siltstone commonly grades between silty sandstone and sandy siltstone; soft; fragile; trace thin coal beds. Tuffaceous Siltstone/ Tuffaceous Claystone (6330' - 6390') = light gray to light brownish gray with light olive gray secondary hues; soft and fragile; irregular, rounded cuttings; silty to clayey to slightly gritty texture; dull to sparkly luster; soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; yellowish gray siltstone commonly grades between sandy siltstone and silty sandstone; soft; fragile. Sand/ Conglomeratic Sand/ Tuffaceous Sandstone (6390'- 6450') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, white, black; very fine to very coarse upper, dominantly fine upper to medium upper; angular to subrounded, dominantly subangular; poorly sorted; disaggregated with ashy matrix common; very fragile. 17 CANRIG J Kalotsa 3 Tuffaceous Siltstone (6470'- 6540') = olive gray to brownish gray with medium dark gray to medium gray secondary hues; stiff consistency; pdc disaggregated; earthy fracture; tabular to wedgelike and platy cuttings habit; greasy to earthy luster; silty to gritty texture; common black carbonaceous material; non calcareous. Coal (6540' - 6570') = black to brownish black; hard and brittle to moderately hard and crunchy; pdc disaggregated; splintery, hackly fracture; dominantly fine scaly and flaky to wedgelike and bladed; resinous luster; abrasive texture, trace smooth faces observed; thick coal bed; moderate to heavy outgassing. Tuffaceous Sandstone (6570'- 6640') = light olive gray to olive gray and medium dark gray secondary hues; quartz and feldspar framework; lower very fine to upper very fine; moderate to well sorted; subrounded to rounded; moderate to high sphericity; pdc disaggregated; soft to easily friable; slay mineral cement; tuffaceous matrix; dominantly floating fabric, trace point contact; non calcareous. Tuffaceous Siltstone (6640'- 6700') = brownish gray to olive gray with medium dark gray and brownish black secondary hues; crumbly to pulverulent tenacity; earthy fracture; tabular to wedgelike and often shapeless cuttings habit; dull, earthy luster; very silty, gritty texture; non calcareous; common thin to moderately thick coal present throughout interval; weak to moderate outgassing observed. Tuffaceous Sandstone (6700'- 6780) = olive gray to brownish gray with medium to medium dark gray secondary hues; quartz and feldspar framework; lower very fine to upper fine grains; well to moderately sorted; subangular to subrounded; moderate to high sphericity, pdc disaggregated; firm friable to moderately hard, trace easily friable; clay mineral cement; tuffaceous matrix support; floating, point contact, long contact fabric; common black carbonaceous material suspended in sample; common coals throughout interval; weak outgassing observed. Tuffaceous Siltstone (6780' - 6830') = olive gray to brownish gray with medium gray and medium dark gray secondary hues; brittle to crumbly tenacity; earthy fracture; tabular to wedgelike and platy cuttings habit; dull, earthy luster; silty to gritty texture; non calcareous. Sand/ Tuffaceous Sandstone ( 6830'— 6900') = olive gray to brownish gray with medium dark gray secondary hues; quartz and feldspar dominant framework; upper very fine to upper fine grains; well to moderately well sorted; subangular to subround; moderate to high sphericity; unconsolidated sand grains; pdc disaggregated sandstone; firm friable to firm; clay mineral cement; tuffaceous matrix support; floating, point contact, long contact fabric; common black carbonaceous material; trace mica; trace red, reddish orange, pink; yellow lithics; no reaction to 10% hcl in sample. Sand (6900'- 6970) = medium light gray to medium dark gray with light olive gray hues; dominantly quartz and feldspar framework; lower very fine to upper fine with trace lower coarse grains; poor to moderately sorted; subangular to subrounded; high to moderately high sphericity; unconsolidated sand grains; common black carbonaceous material, trace coal beds; no to weak outgassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (6970'- 7020') = light gray to very light olive gray with trace medium gray; soft to slightly firm; irregular to shapeless; silty to clayey texture; dull, earthy to waxy luster; hydrophilic moderately soluble and expansive. Coal/ Carbonaceous Shale (7020' - 7080') = black with brownish black and grayish black secondary hues; hard; blocky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly silty texture; resinous to slightly earthy luster; bituminous with trace carbonaceous shale; silty; trace to common outgassing bubbles present. 18 CANRIG /f J— Kalotsa 3 Tuffaceous Siltstone/ Tuffaceous Claystone (7080' - 7140') = light gray to light brownish gray with light olive gray secondary hues; soft and fragile; irregular, rounded cuttings; silty to clayey to slightly gritty texture; dull to sparkly luster; soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; brownish gray siltstone commonly grades between sandy siltstone and silty sandstone; soft; fragile. Sand (7140' - 7200) = light gray to light brownish gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray and black; very fine lower to fine upper, dominantly fine lower; angular to subangular; well sorted; unconsolidated with common medium light to light gray sandstone; soft to firm; fragile; very fine lower; non calcareous; occasionally grading to sandy siltstone. Coal (7200' - 7260') = black with brownish black secondary hues; hard to brittle; finely ground up cuttings; platy to flaky; planar fracture dominant with trace conchoidal; smooth texture; resinous to slightly earthy luster; bituminous; well developed; trace to common, fine, pinpoint outgassing bubbles observed; commonly grading to a less developed carbonaceous shale; silty in part; firm to hard. Tuffaceous Siltstone/ Tuffaceous Claystone (7260' - 7330') = light gray to light brownish gray with light olive gray secondary hues; soft and fragile; irregular, rounded cuttings; silty to clayey to slightly gritty texture; dull to sparkly luster; soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; light brownish gray siltstone grades between sandy siltstone and silty sandstone; soft to fragile; grain supported; non calcareous; abundant coal beds throughout interval. Sand/ Tuffaceous Sandstone (7330'- 7390') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to medium gray and light greenish gray, black; very fine lower to fine upper, dominantly fine lower; angular to subangular; very well sorted; dominantly disaggregated with dirt white ashy matrix common; very fragile; supports loose sand grains; non calcareous. Tuffaceous Sandstone/ Sand (7390' - 7440') = very light gray to grayish white with abundant faint secondary hues; soft to fragile and pulverulent; irregular shaped; crunchy; non calcareous; ashy matrix supports loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to very coarse upper, dominantly fine upper to medium upper; poor to fair sorting. Coal (7450' - 7480') = black to trace brownish black; brittle to crunchy and pulverulent tenacity; blocky fracture; tabular, pdc disaggregated; tabular to wedgelike, bladed, and elongated cuttings habit; resinous luster; smooth to matte faces with abrasive and sharp edges, moderately thick structure; weak to moderate outgassing observed. Tuffaceous Siltstone (7480'- 7580) = olive gray to brownish gray and brownish black; tough and brittle; earthy fracture; tabular to wedgelike cuttings habit; dull earthy luster; very silty to granular texture; bedded with hard sandstone; non calcareous; common thick to moderately thick coals throughout the interval; moderate to heavy outgassing observed. Tuffaceous Sandstone (7580'- 7650') = olive gray to brownish gray with medium dark gray secondary hues; quartz and feldspar framework; upper very fine to upper fine grains; poor to moderately sorted; subangular to subrounded, occasionally angular; moderate to high sphericity; pdc disaggregated; hard to moderately hard; clay mineral cement; tuffaceous matrix support; dominantly floating grain and point contact; common thin coals throughout interval; trace tuff; trace orange and yellow lithics; common black carbonaceous material. 19 CANRIG Kalotsa 3 Sand (7650' - 7740') = medium light gray to medium gray to medium dark gray; strong salt and pepper appearance; dominantly quartz and feldspar; upper fine to lower medium grains, occasionally lower to upper course; poor to moderately sorted; angular to subangular and subrounded; moderate to high sphericity, trace poor sphericity; unconsolidated grains; trace pink, red, reddish orange, light green and light blue lithics. Tuffaceous Siltstone (7740'- 7780') = olive gray to olive brown to brownish black; brittle to crumbly tenacity; earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; smooth and clayey to a slightly silty texture; bedded with sandstone, claystone and abundant coal; moderate to heavy outgassing observed; no reaction to 10% hcl in sample. Coal (7780' - 7820') = black; hard; flaky to platy; planar fracture dominant with conchoidal and birdeye common; smooth texture; resinous luster; weak trace outgassing bubbles observed. Tuffaceous Siltstone (7850' - 7920') = olive gray to olive brownish gray to brownish black; very crumbly to pulverulent tenacity; earthy fracture; tabular to wedgelike and platy cuttings habit; greasy to dull, earthy luster; clayey to silty texture and commonly slightly gritty; trace black microthin carbonaceous laminations; trace suspended carbonaceous fragments; non -calcareous. Tuffaceous Sandstone/Sandstone (7920'- 8000') = light medium gray to medium gray to medium dark gray with olive gray secondary hues; quartz and feldspar framework; lower very fine to lower fine sand grains; moderate to well sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; firm friable to moderately hard; clay mineral cement; tuffaceous matrix support; floating and point contact fabric observed; trace carbonaceous material present; medium dark gray to olive gray sandstone; fine grained; well sorted; dominantly subrounded; moderately to high sphericity; moderately hard to hard; clay mineral cement; grain support; trace carbonaceous material; trace mica; non calcareous. Sand/Sandstone/Conglomeratic Sandstone (8000'- 8090') = medium to medium light gray with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, black and light greenish gray; very fine lower to very coarse upper with 3mm fragments, dominantly fine upper to medium lower; angular to subangular; poorly sorted; disaggregated to ashy supporting matrix to sandstone; fine to medium; salt and pepper; hard very calcareous cement; common light gray to grayish brown sandstone; firm to fragile; non calcareous; grades between sandy siltstone and silty sandstone. Tuffaceous Sandstone/Sand (8090' - 8150') = very light gray to grayish white with very faint multicolored secondary hues; soft to fragile and pulverulent; crunchy acts as supporting matrix for loose sand grains; clear to translucent quartz and volcanic glass, trace dark lithics; very fine lower to medium lower, dominantly fine; angular to subangular; very well sorted; moderately calcareous. Sand/Tuffaceous Sandstone/Conglomeratic Sand (8160'- 8210') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace darker liths with dusky red common; very fine upper to very coarse upper; angular to subangular; poorly sorted; very loosely supported by grayish white ash matrix; soft; fragile to pulverulent; crunchy; non calcareous. Tuffaceous Sandstone/Sand (8210' - 8270') = very light gray to grayish white with very faint multicolored secondary hues; soft to fragile and pulverulent; crunchy acts as supporting matrix for loose sand grains; clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to coarse upper, dominantly fine to medium; angular to subangular; poorly sorted; non calcareous; trace thin coal beds, weak trace outgassing bubbles. 20 CANRIG =f J- Kalotsa 3 Sand/Sandstone/Conglomeratic Sand (8270'- 8330') = medium to medium light gray with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, black and light greenish gray; very fine upper to very coarse upper, dominantly fine to medium; angular to subangular; poor to fair sorting; disaggregated; non calcareous. Coal/Carbonaceous Shale (8330'- 8380') = black with brownish black secondary hues, very firm to hard and brittle; finely ground up, flaky cuttings; planar fracture dominant with trace conchoidal and birdeye, smooth texture; resinous luster bituminous with trace silty, carbonaceous shale; firm; earthy; common to abundant outgassing bubbles present. Tuffaceous Sandstone/Sand (8380'- 8450') = very light gray to grayish white with very faint multicolored secondary hues; soft to fragile and pulverulent; crunchy acts as supporting matrix for loose sand grains; clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to coarse upper, dominantly fine to medium; angular to subangular; poor to fair sorting; non calcareous; common to abundant thin coal beds throughout interval; trace weak outgassing bubbles observed. Sand/Tuffaceous Sandstone/Conglomeratic Sand (8450'- 8510') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace darker liths with dusky red common; very fine upper to very coarse upper, dominantly fine lower to medium upper; angular to subangular; poorly sorted; very loosely supported by grayish white ash matrix; soft; fragile to pulverulent; crunchy; non calcareous; scattered thin coal beds. Tuffaceous Sandstone/Sand (8510' - 8570') = very light gray to grayish white with very faint multicolored secondary hues giving it a mottled appearance; irregular shaped; fragile to pulverulent; crunchy acts as supporting matrix for loose sand grains; clear to translucent quartz and volcanic glass, light to dark gray, dusky red and pale rose; very fine upper to very coarse upper, dominantly fine upper to medium upper; angular to subangular; poorly sorted; non calcareous. Sand/Tuffaceous Sandstone (8570'- 8640') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, light green, pale rose and dusky red; very fine lower to trace very coarse upper, dominantly fine lower to medium lower, angular to subangular; well to very well sorted; dominantly unconsolidated with scattered ashy supporting matrix; grayish white; fragile; non to slightly calcareous. Tuffaceous Sandstone (8640' - 8710') = light gray to medium light gray to medium gray; clear to translucent quartz and feldspar framework; lower very fine to upper fine grains with trace upper coarse grains; well to moderately sorted; angular to subangular; moderate to high sphericity; PDC disaggregated; easily friable to firm friable; clay mineral cement; tuffaceous matrix support; floating and point contact fabric; trace carbonaceous material suspended in sample; no reaction to 10% HCI. Sand (8710' - 8770') = medium dark gray to dark gray with olive gray secondary hues; dominantly clear to translucent quartz and feldspar; lower very fine to upper fine grains, very trace 3mm pebbles, well to very well sorted, subangular to subrounded; moderate to high sphericity; unconsolidated grains, trace carbonaceous material; trace green, reddish orange, yellow lithics. Tuffaceous Siltstone (8770' - 8820') = olive gray to brownish gray with medium dark gray secondary hues; PDC disaggregated; crumbly to pulverulent tenacity; earthy fracture; tabular to platy and often wedgelike cuttings habit; dull earthy luster; silty to slightly gritty texture; bedded with coal and carbonaceous shale; moderate outgassing observed. Coal/Carbonaceous Shale (8870' - 8890') = black to brownish black; brittle to brittle and crumbly; hackly fracture; PDC pulverized; wedgelike to tabular and irregular cuttings habit; resinous luster; abrasive to matte texture; thin structure; trace black microthin laminations; weak to moderate outgassing observed. 21 CAN.RIG J Kalotsa 3 Sand/Tuffaceous Sandstone (8890' - 8980') = light gray to medium light gray to medium gray; dominantly clear to translucent quartz and feldspar; lower very fine to lower medium grains; moderate to well sorted; subangular to subrounded and occasionally angular; moderate to high sphericity; unconsolidated grains; common carbonaceous material; light gray tuffaceous sandstone; fine grained; subangular to subrounded; moderate to high sphericity; PDC disaggregated; easily friable; calcite cement; tuffaceous matrix; floating contact, point contact fabric, trace suspended carbonaceous material; moderately calcareous. Tuffaceous Sandstone (8980' - 9050) = very light gray to medium gray throughout; quartz and feldspar dominant framework; upper very fine to upper fine and occasionally lower medium grains; moderately to well sorted; angular to subangular and subrounded; high sphericity; PDC disaggregated; easily friable to firm friable; clay mineral cement; tuffaceous matrix; floating, point contact and trace long contact fabric; common tuffaceous material; non calcareous; trace thin coals throughout interval; weak outgassing. Tuffaceous Siltstone (9050' - 9100') = olive gray to brownish gray with medium dark gray secondary hues; dominantly tough and brittle to crunch but also crumbly tenacity; earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; silty to gritty texture; trace black carbonaceous microthin laminations and fragments suspended; non calcareous. Tuffaceous Sandstone/Sand (9120'- 9210) = very light gray to medium gray; dominantly clear and translucent quartz and feldspar framework; lower very fine to upper fine, trace coarse grains; moderate to well sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; firm friable to moderately hard; clay mineral cement; tuffaceous matrix; floating, point contact; trace suspended carbonaceous material; quartz and feldspar dominant sand; lower very fine to upper fine grains; moderate to high sphericity; unconsolidated; no reaction to 10% HCI. Sand (9230' - 9265') = medium light gray to medium dark gray; dominantly clear to translucent quartz and volcanic glass; upper very fine to medium size grains with trace coarse grains; moderately sorted; subangular to subrounded trace angular; moderate to high sphericity; unconsolidated sand grains; trace carbonaceous material; trace thin to moderately thick coals throughout interval; weak to moderate outgassing. 22 CANRIG Kalotsa 3 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution Jacob Dunston A Washed and Dried 1423'— 9265' 30' Hilcorp Alaska LLC Reference 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Jacob Dunston B Washed and Dried1423' — 9265' 30' Hilcorp Alaska LLC Reference 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Jacob Dunston C Washed and Dried 1423'— 9265' 30' Hilcorp Alaska LLC Reference 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 23 CANRIG J ! Kalotsa 3 4 DRILLING DATA 4.1 Surveys Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section Incr ft Dogleg Rate 0/100ft 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 202.41 0.49 56.58 202.41 0.43 0.66 0.21 0.27 231.53 1.07 41.16 231.52 0.71 0.94 0.39 2.11 292.67 3.58 341.46 292.62 2.95 0.71 2.59 5.20 354.46 5.90 334.08 354.19 7.64 -1.29 7.67 3.88 414.96 9.24 332.48 414.16 14.74 -4.89 15.53 5.52 476.84 11.66 330.52 475.00 24.59 -10.27 26.55 3.96 538.06 13.05 326.91 534.80 35.77 -17.08 39.28 2.60 599.96 14.50 328.58 594.93 48.24 -24.94 53.55 2.42 663.70 17.12 329.55 656.25 63.14 -33.86 70.47 4.13 725.79 19.25 332.22 715.24 80.07 -43.26 89.47 3.68 787.91 21.72 332.37 773.42 99.32 -53.37 110.88 3.99 849.94 23.59 333.72 830.66 120.62 -64.19 134.47 3.12 912.71 25.00 334.93 887.87 143.90 -75.37 160.06 2.39 975.68 26.83 335.23 944.51 168.86 -86.96 187.37 2.90 1037.96 28.75 335.70 999.60 195.28 -99.01 216.20 3.12 1100.55 31.12 336.56 1053.83 223.84 -111.64 247.26 3.85 1162.66 33.39 337.44 1106.36 254.36 -124.59 280.28 3.73 1225.19 34.76 338.96 1158.15 286.89 -137.59 315.22 2.57 1287.80 35.50 339.29 1209.35 320.55 -150.43 351.20 1.23 1349.61 35.08 340.65 1259.80 354.10 -162.66 386.88 1.45 1387.92 34.88 341.62 1291.20 374.88 -169.76 408.84 1.54 1438.14 34.34 342.32 1332.53 402.00 -178.59 437.36 1.33 1501.25 35.09 341.57 1384.40 436.18 -189.73 473.30 1.37 1563.57 35.52 340.82 1435.26 470.27 -201.34 509.32 0.98 1627.17 35.91 340.49 1486.89 505.30 -213.64 546.43 0.69 1688.88 34.36 339.70 1537.36 538.70 -225.73 581.92 2.62 1751.23 34.23 339.35 1588.87 571.61 -238.02 617.02 0.38 1812.57 34.56 338.97 1639.48 603.99 -250.34 651.62 0.65 1875.20 34.80 338.90 1690.98 637.25 -263.15 687.20 0.39 1937.95 35.10 339.31 1742.41 670.83 -275.98 723.09 0.60 2000.00 35.37 338.63 1793.10 704.25 -288.83 758.84 0.77 2061.51 33.32 339.39 1843.88 736.64 -301.26 793.48 3.40 2123.69 33.46 339.59 1895.80 768.69 -313.25 827.67 0.28 24 CANRIG Kalotsa 3 Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N(+), S(-,) Departure (ft) E(+), W(-) Vertical Section Incr ft Dogleg Rate °/100ft 2186.05 34.10 339.63 1947.63 801.19 -325.33 862.30 1.03 2247.79 34.54 338.88 1998.63 833.74 -337.66 897.06 0.98 2310.38 35.00 338.64 2050.04 867.01 -350.60 932.69 0.78 2371.58 33.84 339.67 2100.52 899.33 -362.91 967.23 2.12 2432.06 34.01 339.73 j 2150.71 930.99 -374.62 1000.96 0.28 2495.94 35.01 339.57 2203.35 964.92 -387.21 1037.11 1.58 2557.78 35.55 339.69 2253.83 998.40 -399.64 1072.79 0.88 2620.33 34.36 341.18 2305.10 1032.17 -411.65 1108.61 2.35 2681.95 34.83 340.91 2355.82 1065.25 -423.01 1143.59 0.80 2744.18 35.33 340.85 2406.74 1099.05 -434.73 1179.34 0.81 2807.60 33.83 341.93 2458.96 1133.16 -446.22 1215.34 2.55 2870.11 34.00 341.83 2510.83 1166.31 -457.07 1250.22 0.28 2931.22 34.66 342.08 2561.29 1199.08 -467.74 1284.68 1.10 2994.98 35.03 341.22 2613.63 1233.66 -479.21 1321.11 0.97 3056.78 35.25 340.85 2664.16 1267.29 -490.77 1356.67 0.49 3117.97 35.45 340.43 2714.07 1300.69 -502.51 1392.06 0.52 3180.69 35.89 340.83 2765.03 1335.20 -514.64 1428.62 0.80 3242.65 34.30 341.78 2815.72 1368.93 -526.06 1464.23 2.72 3305.30 34.20 341.58 2867.51 1402.41 -537.14 1499.49 0.24 3367.87 34.60 340.63 2919.13 1435.85 -548.59 1534.83 1.06 3429.01 34.59 339.97 2969.46 1468.53 -560.29 1569.53 0.62 3491.47 34.59 339.04 3020.89 1501.75 -572.71 1604.95 0.84 3553.38 34.79 338.02 3071.79 1534.53 -585.61 1640.11 0.99 3615.47 34.79 337.19 3122.78 1567.29 -599.11 1675.42 0.77 3677.58 34.08 339.39 3174.01 1599.91 -612.10 1710.46 2.31 3740.10 33.84 338.79 3225.86 1632.54 -624.57 1745.33 0.66 3802.60 33.48 341.04 3277.88 1665.07 -636.47 1779.94 2.08 3864.10 34.74 341.36 3328.80 1697.72 -647.58 1814.43 2.07 3926.53 35.94 340.87 3379.72 1731.88 -659.27 1850.53 1.98 3988.12 35.75 340.39 3429.65 1765.91 -671.23 1886.58 0.56 4049.71 36.98 340.17 3479.25 1800.28 -683.56 1923.08 2.00 4111.36 36.82 339.52 3528.55 1835.03 -696.31 1960.06 0.68 4173.98 36.95 338.60 3578.63 1870.13 -709.74 1997.59 0.91 4235.66 35.77 339.21 3628.31 1904.24 -722.91 2034.10 1.99 4297.62 36.38 339.06 3678.39 1938.34 -735.91 2070.53 0.98 4359.49 35.65 340.53 3728.43 1972.48 -748.47 2106.88 1.82 4421.15 36.32 340.63 3778.32 2006.65 -760.52 2143.09 1.10 4484.41 35.90 342.40 3829.43 2042.00 -772.34 2180.37 1.79 4546.85 36.32 342.50 3879.88 2077.09 -783.43 2217.17 0.68 25 CANRIG J Kalotsa 3 Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section Incr ft Dogleg Rate °/t00ft 4609.53 34.12 342.16 3931.08 2111.53 -794.40 2253.31 3.53 4672.12 33.60 341.91 3983.05 2144.69 -805.15 2288.18 0.85 4735.19 32.83 341.50 4035.82 2177.50 -816.00 2322.73 1.28 4797.42 32.44 341.03 4088.22 2209.27 -826.78 2356.28 0.74 4859.70 1 31.69 340.55 4141.00 2240.49 -837.65 2389.33 1.28 4922.32 32.74 340.96 4193.99 2272.01 -848.65 2422.70 1.72 4984.73 32.20 344.14 4246.65 2303.96 -858.71 2456.19 2.87 5046.31 33.13 344.94 4298.49 2336.00 -867.56 2489.40 1.66 5108.39 33.43 344.38 4350.38 2368.84 -876.57 2523.43 0.70 5169.52 31.25 345.53 4402.03 2400.42 -885.07 2556.09 3.70 5231.36 32.27 345.71 4454.61 2431.96 -893.15 2588.59 1.65 5293.68 33.41 345.92 4506.96 2464.72 -901.43 2622.31 1.83 5355.97 35.01 346.37 4558.48 2498.72 -909.81 2657.25 2.60 5415.68 35.23 346.27 4607.32 2532.10 -917.94 2691.51 0.39 5478.83 35.34 345.99 4658.87 2567.51 -926.68 2727.90 0.31 5540.48 35.61 345.83 4709.07 2602.21 -935.39 2763.60 0.46 5603.20 34.81 349.74 4760.33 2637.54 -943.05 2799.58 3.82 5665.46 35.05 349.73 4811.37 2672.61 -949.40 2834.92 0.39 5726.88 33.02 348.15 4862.27 2706.35 -955.98 2869.05 3.61 5791.06 33.71 348.97 4915.88 2740.94 -962.97 2904.12 1.28 5853.87 32.86 348.63 4968.38 2774.75 -969.67 2938.36 1.38 5916.97 33.63 348.25 5021.15 2808.64 -976.61 2972.75 1.26 5977.64 33.89 347.51 5071.59 2841.61 -983.69 3006.30 0.80 6040.62 33.57 346.87 5123.97 2875.71 -991.44 3041.14 0.76 6102.65 32.61 346.11 5175.93 2908.64 -999.35 3074.90 1.68 6165.14 33.55 345.74 5228.30 2941.72 -1007.64 3108.94 1.53 6222.23 33.33 345.82 5275.94 2972.22 -1015.37 3140.34 0.40 6291.10 33.48 344.71 5333.43 3008.89 -1025.01 3178.20 0.92 6353.97 32.79 1 343.58 5386.08 3041.95 -1034.40 3212.55 1.48 6416.75 33.60 345.16 5438.61 3075.05 -1043.65 3246.89 1.89 6478.96 32.78 347.74 5490.68 3108.15 -1051.64 3280.85 2.63 6541.96 32.57 347.34 5543.71 3141.36 -1058.97 3314.71 0.48 6604.68 31.20 346.07 5596.96 3173.60 -1066.58 3347.73 2.43 6667.67 29.90 347.43 5651.21 3204.75 -1073.93 3379.64 2.34 6730.77 29.33 347.02 5706.06 3235.16 -1080.82 3410.70 0.95 6792.81 27.67 348.32 5760.58 3264.08 -1087.15 3440.17 2.85 6855.60 26.67 347.36 5816.45 3292.11 -1093.18 3468.70 1.75 6917.23 27.11 347.68 5871.41 3319.32 -1099.21 3496.46 0.76 6979.81 25.65 346.83 5927.47 3346.44 -1105.34 3524.15 2.41 26 CANRIG Kalotsa 3 Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N(+). S(-) Departure (ft) E(+), W(-) Vertical Section Incr ft Dogleg Rate °/100ft 7041.01 23.53 343.94 5983.12 3371.09 -1111.74 3549.57 3.98 7102.76 21.52 343.96 6040.16 3393.82 -1118.28 3573.22 3.26 7164.75 18.97 341.13 6098.32 3414.29 -1124.68 3594.66 4.40 7228.26 17.54 343.07 j 6158.63 3433.22 -1130.81 3614.55 2.45 7289.85 16.39 347.13 6217.54 3450.57 -1135.44 3632.49 2.68 7352.39 15.24 346.97 6277.71 3467.17 -1139.26 3649.47 1.83 7414.40 15.08 347.74 6337.56 3482.99 -1142.81 3665.62 0.42 7474.49 13.16 349.26 6395.83 3497.35 -1145.75 3680.19 3.25 7537.71 10.92 351.46 6457.66 3510.35 -1147.98 3693.24 3.62 7601.40 9.77 351.15 6520.32 3521.65 -1149.70 3704.53 1.80 7662.64 10.14 349.55 6580.63 3532.09 -1151.48 3715.01 0.75 7725.45 8.97 352.17 6642.57 35412.38 -1153.15 3725.32 2.00 7787.87 8.41 351.08 6704.28 3551.7 -1154.52 3734.61 0.93 7850.99 7.91 349.79 6766.76 3560.54 -1156.01 3743.48 0.84 7913.3 6.96 358 6828.54 3568.53 -1156.9 3751.36 2.28 7976.49 6.8 359.41 6891.28 3576.1 -1157.07 3758.62 0.36 8038.62 6.31 356.88 6953 3583.18 -1157.29 3765.44 0.92 8100.57 6.34 356.45 7014.57 3589.99 -1157.69 3772.04 0.09 8162.83 6.68 356.95 7076.43 3597.04 -1158.1 3778.87 0.56 8226.07 6.66 355.75 7139.24 3604.37 -1158.56 3785.99 0.22 8285.79 6.24 351.15 7198.59 3611.03 -1159.32 3792.56 1.11 8350.81 5.54 348.13 7263.26 3617.59 -1160.51 3799.18 1.17 8413.63 6.08 349.47 7325.76 3623.83 -1161.74 3805.5 0.88 8475.68 7.01 354.25 7387.4 3630.83 -1162.72 3812.46 1.72 8538.74 7.04 355.25 7449.99 3638.51 -1163.43 3819.98 0.2 8600.45 5.68 350.42 7511.32 3645.29 -1164.25 3826.69 2.37 8663.77 6.03 353.1 7574.31 3651.67 -1165.17 3833.05 0.7 8724.96 5.91 350.91 7635.17 3657.98 -1166.05 3839.32 0.41 8787.89 6.09 349.92 7697.76 3664.47 -1167.15 3845.84 0.33 8849.22 5.24 346.58 7758.78 3670.39 -1168.37 3851.85 1.5 8911.25 4.99 343.88 7820.57 3675.74 -1169.77 3857.37 0.56 8974.93 5.11 342.08 7884 3681.09 -1171.41 3862.97 0.31 9036.86 4.92 340.59 7945.7 3686.22 -1173.15 3868.38 0.36 9099.01 4.3 338.41 8007.64 3690.91 -1174.89 3873.38 1.04 9162.33 3.96 341.64 8070.8 3695.19 -1176.45 3877.93 0.66 9228.73 3.58 348.05 8137.06 3699.39 -1177.6 3882.29 0.86 9265 3.58 348.05 8173.25 3701.61 -1178.07 3884.54 0 'Projected 27 CANRIG �\ ) o: � § / } \ 2 \ $ § ° \ \ f CJ Ci \ ) Lo M A 5 = G 0) cc © e ) / \/ / \ } ] § 2 B a , Cl) _ o: � N N 0 V y d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U- (n U vvvvvvaavvvvvv 00000000000000 c 00000 00000000000000 V op000 oo oo o oo00000 E OJ r OJ a D OJ N M moo M 7 M N N 7 N M Cl) M N N W M O N O M (q 000000000o0oo M M p) M tD M M M (O M r M 1 n M 1f. M N M M M � M V. M M = �0)0)m O O O O O O O O O O O M M N N N N N m NNNN NMM4 V 7Ma?[ta"Tv7 � q 0 0 O 0 LL] 0 0 0 0 0 0 0 0 0 0 0 .O fA' M N tq "I MN NNNNNN N NNN N —0000 000 o MOM oO o o r 000000000 (ON 000000000 000 0 p w M N N O lRF rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn O (9 O OO O W O MM O 0 7 0 O 0 q0 0 0 OO 0 M(qM 0 0 0 V0 0 0 0 ROO 0 0 OO 0 N Oe N N 0 �q 0 �nnn 0 0 0 c') N (M N �(i N of N �tO N N tO N V1 N OfOOOOO N N N N N N N V LL N N N 4) d JU a om �nmrn E O N O) O) N(00)OJ O 00(ON N a a rnCrn�� rn mwlznnlz- O N N M M fO r 0 l0 t0 (D �0 (0 - 0 t0 �0 i0 L0 ;0 (O O (O(OMO)O r rOr n r O) (O CLMn0(q a-MMe- N O It N M(M co — vrat) N — m lq tq > pNNNN r m m 0 r u,D� �i — v — v — n — n — o — o — n 0 0 N" ��MM 0 M (qn OD aD OD O] OJ M M OO OJ 7 (�O OD 0 T 0 O) 0 d) 0 O 0 .N -N W M W V O) r O) O Oi N Oi O Oi O Oi N Oi M m M O) M CA M D) M M O) M D �� N�MMM N(q MfD MfOravmnrrrrnr (O d'Mrr(o Z N M 7 �q (O (O (O r W a0 aO OD OD OD 00 d D OOMMM MOJ N OOD7 aNl04�iq iq i0 t0 t0 OC � N 7 NNN V 77 O(O N (q ? (q '7 7NNr R OD ODr O N (O NN OR (O N(O(O NN l0 � nrrnn O N rrrrnrrnnr_n_rnnn V tq (O r r r aD 0 0) O) O) O) O) O) d 0 0 co 0 co 0(D ID co co 0 cow N t L m O) � d � Vl ov �UWu II Q _N N It O O 2 (D U) 2 2 N 0 V y d O N `. LL > C d O U N C � C N O U�coU II II II U- (n t L m O) � d � Vl ov �UWu II Q _N N It O O 2 (D U) 2 2 a e O o 0 0 0 0 0 0 0 N M 7 0 0 0 rn C`02�aZ <<02 !y ``02/�2�9 1 -IOL- ``02/19 `LOQ/9��9 <`02 ``02�A 1-9 !<02 1a.Z, 19 1,/0e/s/9 ``0L `20. 0 M 5 SHOW REPORTS Kalotsa 3 CANRIG 31 CAN I ,IG Hydrocarbon Show Report # 1 Operator: Hilcorp Alaska, LLC Well: Kalotsa 3 API Number 50-133-20661-00-00 Field: Ninilchik Unit Date: 6/14/2017 Rig: Saxon 169 Time: 9:30 PM County: Kenai Peninsula Borough Depth Istart IlEnd State: Alaska 5275' MD 5290' MD Country: United States of America 4491' TVD I 4503' TvD Averages Pixler Plot 00°° Before During After Maximum ROP (fph) 34 fUhr 148 ft/hr 144 fUhr 191 fUhr WOB 6 klbs 2 klbs 4 klbs 5 klbs RPM 0 rpm 0 rpm 79 rpm 79 rpm two PP 2086 psi 2139 psi 2175 psi 2177 psi ig Mud Weight 9.3 lbs/gal 9.3 lbs/gal 9.3lbs/gal 9.3 lbs/gal E Chloride 33,000 33,000 33,000 33,00010 ` Total Gas 176 871 183 882 C1 (ppm) 16,508 148,101 42,154 150,493 C2 m - - - 2 3 4 C3 m C4 (ppm) CS m Lithology Tuffaceous Sandstone: Olive gray to brownish gray with medium gray and medium dark gray secondary hues; quartz and feldspar framework; lower very fine to lower fine sand grains; Well to very well sorted; subrounded to rounded; moderate to high spheriticy; PDC disaggregated; friable to firm friable; clay mineral cement; Tuffaceous matrix; point contact, Long contact, floating contact fabric; thin bedding; trace carbonaceous material, Non calcareous. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount Color n/a Amount n/a Color n/a n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud No Comments Tyonek sand between T10 & T10A, Gas show. Report by: Mar uel Moseba r" CANMG Hydrocarbon Show Report # 2 Operator: Hilcorp Alaska, LLC Well: Kalotsa 3 API Number 50-133-20661-00-00 Field: Ninilchik Unit Date: 6/15/2017 Rig: Saxon 169 Time: 6:20 AM County: Kenai Peninsula Borough Depth Start End State: Alaska 5521' MD 5576' MD Country: United States of America 4696' TVD 4738' TVD Averages Pixier Plot Before During After Maximum ROP (fph) 125 ft/hr 148 ft/hr 147 ft/hr 154 ft/hr 100°° WOB 5 klbs 4 klbs 4 klbs 7 klbs RPM 0 rpm 75 rpm 75 rpm 76 rpm 10w PP 2276 psi 2244 psi 2246 psi 2432 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal AS E 100 Chloride 33,000 33,000 33,000 33,000 Total Gas 274 1,800 718 1,800 0 C1 m 22,262 265,224 173,938 268,890 C2 m - - - - 1 2 3 4 Gt < C3 m C4 m - - - CS m - - Lithology Sand: dominantly medium dark gray to dark gray to olive gray; dominantly translucent to opaque quartz and feldspar framework; lower very fine to upper fine grains, common medium sand grains; moderate to well sorted; subangular to subrounded high sphericity; unconsolicated sand grains; trance to common carbonaceous material. Trace pink, dark yellow, light yellow, orange, redish orange lithics; common gray lithics; No reaction to HCL in sample. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount Color n/a Amount n/a Color n/a n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud No Comments Using the Kalotsa 3 Coal Tops, This show is between the T12A & T12B Tyonek sands, Gas show. Report by: Mar uel Moseba CANRIG Dxv.umc Tect�uowcv Lnu. Hydrocarbon Show Report # 3 Operator: Hilcorp Alaska, LLC Well: Kalotsa 3 API Number 50-133-20661-00-00 Field: Ninilchik Unit Date: 6/15/2017 Rig: Saxon 169 Time: 6:15 AM County: Kenai Peninsula Borou hDe"4760' End State: Alaska 5603' MD 5636' MD Count : United States of America TVD 4787' TVD Averages PixlerPlot Before During After Maximum ROP f h) 152 ft/hr 150 ft/hr 126 ft/hr 154 ft/hr 10" WOB 5 klbs 5 klbs 4 klbs 9 klbs RPM 75 rpm 75 rpm 75 rpm 75 rpm low PP 2246 psi 2232 psi 2186 psi 2425 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal AS E 100 Chloride 34,500 34,500 34,500 34,500 10 Total Gas 231 614 416 613 C1 m 32,891 104,961 72,719 105,041 C2 m - - - - z a 4 01103 CIM clM 0,/05 C3 m C4 m CS m Lithology Sand/Tuffaceous Sandstone material: Medium light gray to medium gray with light olive gray hues; clear to translucent quartz and feldspar dominant; upper fine to upper course grains with 2mm pebbles; poor to moderately sorted; subangular to subrounded; moderate to high sphericity; unconsolidated grains; trace pale yellow, reddish orange, green, pinkish red, common; tuffaceous sandstone pdc disaggregated; easily friable; clay mineral cement; very tuffaceous matrix; floating and point contact fabric; common carbonaceous material; non calcareous. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount Color n/a Amount n/a Color n/a n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud No Comments Using the Kalotsa 3 Coal Tops, This show is positioned at T12A Tyonek sands, Gas show. Report by: Mar uel Moseba CANRIG llxu.i.im Teru>-oi.00r Lru. Hydrocarbon Show Report # 4 Operator: Hilcorp Alaska, LLC Well: Kalotsa 3 API Number 50-133-20661-00-00 Field: Ninilchik Unit Date: 6/15/2017 Rig: Saxon 169 Time: 4:09 PM County: Kenai Peninsula Borough De th Start End State: Alaska 6239' MD 6279' MD Country: United States of America 5290' TVD 5323' TVD Averages PixlerPlot Before During After Maximum ROP (fph) 141 ft/hr 146 ft/hr 143 ft/hr 151 fUhr +0000 WOB 4 klbs 4 klbs 5 klbs 7 klbs RPM 74 rpm 75 rpm 74 rpm 75 rpm PP 2414 psi 2321 psi 2574 psi 2614 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.41bs/ al 9.4 lbs/gal Y_ E 100 Chloride 34,000 34,000 34,000 34,000 t0 Total Gas 187 780 299 780 C1 m 42,265 129,863 56,126 129,863 NhN C2 m - - - - 1 2 3 6 01. CIX3 CM CMF C3 m C4 m - - 05 m - - Lithology Sand/Conglomeratic Sand/Tuffaceous Sandstone: Very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, white, black and dusky red; Very fine to very coarse upper with pebble fragments 5mm, Dominantly fine upper to medium upper; Angular to subrounded, Dominantly subangular; Poorly sorted; Disaggregated with ashy matrix common; Very fragile. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount n/a Color n/a Amount n/a Color n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud INo Comments Tyonek T6. Gas show. Report by: Leigh Ann Rasher CA RIG Dx,,,,; Tac..... ocr L n, Hydrocarbon Show Report # 5 Operator: Hilcorp Alaska, LLC Well: Kalotsa 3 API Number 50-133-20661-00-00 Field: Ninilchik Unit Date: 6/17/2017 Rig: Saxon 169 Time: 3:51 AM County: Kenai Peninsula Borou hDe th Start End State: Alaska 7626' MD 7666' MD Country: United States of America 6544' TVD 6583' TVD Averages Pixler Plot Before During After Maximum ROP (fph) 56 ft/hr 72 ft/hr 75 ft/hr 120 ft/hr 10W0 WOB 2 klbs 4 klbs 3 klbs 4 klbs RPM 73 rpm 75 rpm 75 rpm 76 rpm 1000 PP 2829 psi 2842 psi 2846 psi 2849 psi Mud Weight 9.6 lbs/gal 9.6 lbs/gal 9.6 lbs/gal 9.6 lbs/gal E 1n Chloride 33,000 33,000 33,000 33,000 ' m Total Gas 139 417 349 417 _ C1( m) 35,872 70,754 57,236 110,354 C2 m) - - - - 1 2 3 4 0,= 0wa 0„04 c,ws C3 (ppm) C4( m) C5 m Lithology Tuffaceous Sandstone: Olive gray to brownish gray with medium dark gray secondary hues; Quartz and Feldspar framework; Upper very fine to upper fine grains; Poor to moderately sorted; Subangular to subrounded, occasionally angular; Moderate to high sphericity; PDC disaggregated, Hard to moderately hard; Clay mineral cement; Tuffaceous matrix support; Dominantly floating grain and point contact; Common thin coals throughout interval; Trace tuff; Trace orange and yellow lithics; Common black carbonaceous material. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a i Type n/a Intensity n/a Color None Amount Color n/a Amount n/a Color n/a n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud INo Comments Tyonek 65. Gas show. Report by: Leigh Ann Rasher CA RIG ... Hydrocarbon Show Report # 6 Operator: Hilcorp Alaska, LLC Well: Kalotsa 3 API Number 50-133-20661-00-00 Field: Ninilchik Unit Date: 6/19/2017 Rig: Saxon 169 Time: 4:29 PM County: Kenai Peninsula Borough Depth Start 1 End State: Country: Alaska United States of America 8462' MD 8502' MD 7373' TVD 7413' TVD Averages Pixler Plot Before During After Maximum ROP (fph) 55 ft/hr 29 fUhr 75 ft/hr 106 ft/hr 10000 WOB 5 kibs 5 klbs 11 klbs 10 klbs RPM 0 rpm 72 rpm 73 rpm 75 rpm law PP 1794 psi 1789 psi 1823 psi 1911 psi Mud Weight 9.8 lbs/gal 9.8 lbs/gal 9.8 lbs/ al 9.8 lbs al E loo Chloride 34,000 34,000 34,000 34,000 ' 10 ; ; Total Gas 113 322 162 322 C1 m 19,996 57,603 39,080 57,603 C2 m - - - - 1 : s a „� M. 0,,C, C3 m - - - C4 m - - - CS m - - - Lithology Sand/Tuffaceous Sandstone/Conglomeratic Sand: very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace darker liths with dusky red common; very fine upper to very coarse upper, dominantly fine lower to medium upper; angular to subangular; poorly sorted; very loosely supported by grayish white ash matrix; soft; fragile to pulverulent; crunchy; non calcareous; scattered thin coal beds. Cuttings Anal sis Odor I n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount Color n/a Amount n/a Color n/a n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud lNo Comments Using the Kalotsa 3 Coal Tops, This show is between the T141 & T142 Tyonek Sands, Gas show. "Note thin coal thru section" Report by: Mar uel Moseba CA RIG Ttr,,..o ,n L,, ,. Hydrocarbon Show Report # 7 Operator: Hilcorp Alaska, LLC Well: Kalotsa 3 API Number 50-133-20661-00-00 Field: Ninilchik Unit Date: 6/20/2017 Rig: Saxon 169 Time: 4:04 AM County: Kenai Peninsula Borough De th Start End State: Alaska 9025' MD 9041' MD 7933' TVD 7949' TVD Country: United States of America Averages Pixler Plot Before During After Maximum ROP (fph) 100 ft/hr 92 ft/hr 76 ft/hr 177 ft/hr 100°0 WOB 7 klbs 7 klbs 8 klbs 9 klbs RPM 71 rpm 71 rpm 73rpm 73rpm 1000 PP 2063 psi 2076 psi 2073 psi 2077 psi Mud Weight 9.8 lbs al 9.8 lbs/gal 9.8 lbs/gal 9.8 lbs/gal E 100 Chloride 33,000 33,000 33,000 33,000 Total Gas 122 233 194 233 0 C1 m 20,733 43,400 37,801 43,400 C2 m - - - - 17 1 2 3 6 01= 0„a 0110. 01. C3 m - - C4 m - - CS m - - Lithology Tuffaceous Sandstone: Very light gray to medium gray throughout; quartz and feldspar dominant framework; upper very fine to upper fine and occasionally lower medium grains; moderately to well sorted; angular to subangular and subrounded; high sphericity; PDC disaggregated; easily friable to firm friable; clay mineral cement; tuffaceous matrix; floating, point contact and trace long contact fabric; common tuffaceous material; non calcareous; trace thin coals throughout interval; weak outgassing. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount n/a Color n/a Amount n/a Color n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud INo Comments Tyonek Sands, Gas show. Report by: Mar uel Moseba DAILY REPORTS Kalotsa 3 32 Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 //� /,//♦AA►�►► �RI V REPORT FOR Clint Montague, Robert Wall DATE June 7, 2017 DEPTH 138' PRESENT OPERATION Prepare to pick up Drill Pipe TIME 23:59:59 YESTERDAY 138' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL - FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Rig up. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,232.44 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 AA 1■y��ir�I^ �� IG REPORT FOR Clint Montague, Robert Wall DATE Jun 08, 2017 DEPTH 1025' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 138' 24 HOUR FOOTAGE 887' CASING INFORMATION 16" @ 138' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR1 97/8" Smith MS1519 JF4603 2X13,3X15 123' 250' 127' 044 2 -6 -BT -G -X -I -CT -TD Rat Hole Complete 2 9 7/8" HDBS MM65 12611378 6X13 250' 775' 342 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 675.1 @ 442' 13.3 @ 202' 208.8 217.46001 FT/HR SURFACE TORQUE 6618 @ 163' 0 @ 834' 2436.5 0.00003 AMPS WEIGHT ON BIT 13 @ 590' 0 @ 402' 2.9 4.79081 KLBS ROTARY RPM 50 @ 384' 0 @ 323' 21.9 0 RPM PUMP PRESSURE 1678 @ 1003' 453 @ 183' 1090.2 1570.19995 PSI DRILLING MUD REPORT DEPTH 949' MW 9.10 VIS 127 PV 29 YP 37 FL 9.6 Gels 20/57/71 CL- 750 FC 2/0 SOL 5.8 SD - OIL - MBL 25 pH 9.3 Ca+ - CCI 0.40 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 47 @ 633' 0 @ 513' 15.2 TRIP GAS 0 CUTTING GAS 0 @ 1025' 0 @ 1025' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 8729 @ 635' 117 @ 513' 2691.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1025' 0 @ 1025' 0.0 AVG 25u PROPANE (C-3) 0 @ 1025' 0 @ 1025' 0.0 CURRENT 19u BUTANE (C-4) 0 @ 1025' 0 @ 1025' 0.0 CURRENT BACKGROUND/AVG 15u/30u PENTANE (C-5) 0 @ 1025' 0 @ 1025' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Clay, Sand Completed rig up, picked up drill pipe, serviced Rig, picked up bit and mud motor, and ran into the hole to tag 125'. Drilled a rat hole from DAILY ACTIVITY 125'to 250', pulled out of the hole, laid down dumb iron, and picked up smart tools. Ran back into the hole to 250' and drilled ahead to SUMMARY 1025'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.00 Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 CANIV REPORT FOR Clint Montague, Robert Wall DATE Jun 09, 2017 DEPTH 1423' PRESENT OPERATION Rig down Cementers TIME 23:59:59 YESTERDAY 1025' 24 HOUR FOOTAGE 398' CASING INFORMATION 16" @ 138' 7 5/8" @ 1412' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1287.80 35.53 339.29 1208.78 SURVEY DATA 1349-61 35.10 340.65 1259.22 1387.92 34.90 341.62 1290.61 BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 97/8" HDBS MM65 12611378 6X13 250' 1423' 1173' 549 1 -1 -JD -G -X -1 -NO -TD TO section DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 223.7 @ 1078' 3.8 @ 1138' 189.0 201.690 FT/HR SURFACETORQUE 7662 @ 1266' 0 @ 1153' 4601.9 7352.46582 AMPS WEIGHT ON BIT 13 @ 1087' 0 @ 1393' 5.1 6.10066 KLBS ROTARY RPM 76 @ 1285' 0 @ 1140' 41.4 74.630 RPM PUMP PRESSURE 2055 @ 1400' 1140 @ 1099' 1730.3 1992.20996 PSI DRILLING MUD REPORT DEPTH 1423' MW 9.10 VIS 77 PV 26 YP 30 FL 9.5 Gels 20/57/71 CL- 800 FC 2/0 SOL 5.8 SO - OIL - MBL 25 pH 9 Ca. - CCI 0.30 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 201 @ 1220' 1 @ 1381' 52.5 TRIP GAS 75u CUTTING GAS 0 @ 1423' 0 @ 1423' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 37781 @ 1221' 175 @ 1382' 9550.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1423' 0 @ 1423' 0.0 AVG 0 PROPANE (C-3) 0 @ 1423' 0 @ 1423' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 1423' 0 @ 1423' 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 1423' 0 @ 1423' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Clay, Sand, Coal Drilled ahead from 1025'to 1423', pumped sweep, circulated hole dean, and pulled out of the hole. Laid down tools, serviced rig, made up DAILY ACTIVITY float and test float equipment. Ran in hole with 7 5/8° casing from 123' to 1412', circulated mud, rigged down casing equipment, rigged up SUMMARY cementing equipment Performed Cement job and began rigging down cement equipment. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 � Y�IV REPORT FOR Clint Montague, Robert Wall DATE Jun 10, 2017 DEPTH 1423' PRESENT OPERATION Picking up Drill Pipe TIME 23:59:59 YESTERDAY 1423' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8" @ 1412' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1423' MW 9.3 VIS 59 PV 26 YP 15 FL 9.8 Gels 3/5/6 CL- 800 FC 1/0 SOL 7.3 SD - OIL - MBL 25 pH 8.2 Ca, - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Completed rigging down cement equipment, prepared rig for upcoming BOP test, and began picking up and racking back drill SUMMARY pipe. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Kalotsa � Y�IV 3 REPORT FOR Clint Montague, Robert Wall DATE Jun 11, 2017 DEPTH 1423' PRESENT OPERATION Running in hole TIME 23:59:59 YESTERDAY 1423' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8" @ 1412' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" VareIV513PDHRU 4008283 4X9,3X10 1423' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1423' MW 9.3 VIS 60 PV 25 YP 16 FL 9.9 Gels 3/4/6 CL- 800 FC 1/0 SOL 7.3 SO - OIL - MBL 25 pH 8 Ca+ CCl MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Perform BOP test, make up BHA, pick up Drill pipe, and tun into hole to 756'. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2,625.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 /�� . 'y/'J�� \I \/ REPORT FOR Clint Montague, Robert Wall DATE Jun 12, 2017 DEPTH 2715' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 1423' 24 HOUR FOOTAGE 1292' CASING INFORMATION 16" @ 138' 7 5/8" @ 1412' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2681.95' 34.83 340.91 2355.82 BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" VareIV513PDHRU 4008283 4X3,3X10 1423' 1292' 9:12 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 284.6 @ 1436' 28.4 @ 2476' 144.0 146.60001 FT/HR SURFACETORQUE 7448 @ 2471' 0 @ 2349' 5893.9 6819.68652 AMPS WEIGHT ON BIT 7 @ 2647' 0 @ 2346' 2.4 3.01820 KLBS ROTARY RPM 81 @ 2299' 0 @ 2042' 68.6 77.280 RPM PUMP PRESSURE 1992 @ 1423' 1136 @ 1477' 1425.1 1546.77002 PSI DRILLING MUD REPORT DEPTH 2643' MW 9.12 VIS 57 PV 10 YP 20 FL 5.0 Gels 7/9/12 CL- 32000 FC 1/2 SOL 3.1 SO 0.20 OIL - MBL 25.0 pH 10.5 Ca+ 40 CCI 1.30 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 425 @ 2079' 1 @ 2583' 63.3 TRIP GAS 0 CUTTING GAS 0 @ 2715' 0 @ 2715' 0.0 WIPER GAS 39u CHROMATOGRAPHY(ppm) SURVEY 0 METHANE (C-1) 77923 @ 2080' 335 @ 2584' 11354.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 2715' 0 @ 2715' 0.0 AVG 0 PROPANE (C-3) 0 @ 2715' 0 @ 2715' 0.0 CURRENT 52u BUTANE (C-4) 0 @ 2715' 0 @ 2715' 0.0 CURRENT BACKGROUND/AVG 8u/15u PENTANE (C-5) 0 @ 2715' 0 @ 2715' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY 60% Tuffaceous Claystone, 20% Sand, 10% Tuffaceous Siltstone DAILY ACTIVITY Continued running into the hole from 756'to shoe at 1412' and re-drilled the rat hole to 1423' plus 20' of new formation at 1443'. Circulated bottoms up, displaced mud system, performed FIT test, and drilled ahead from 1443'to 2468'. Circulated mud and pulled out of the hole from SUMMARY 2468' to 1409' for a wiper trip. Serviced rig and ran back into the hole from 1409' to 2468' and drilled ahead to 2715'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa CANRIG 3 REPORT FOR Clint Montague, Robert Wall DATE Jun 13, 2017 DEPTH 4335' PRESENT OPERATION Dolling Ahead TIME 23:59:59 YESTERDAY 2715' 24 HOUR FOOTAGE 1620' CASING INFORMATION 16" @ 138' 7 5/8" @ 1412' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4297.62' 36.38 339.06 3678.39' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Varel V513PDHRU 4008283 4x9, 3x10 1423' 2912' 20:49 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 207.7 @ 3046' 22.4 @ 3791' 143.6 73.720 FT/HR SURFACETORQUE 8537 @ 4334' 0 @ 3917' 6935.8 1124.65259 AMPS WEIGHT ON BIT 7 @ 3044' 0 @ 4027' 4.1 1.18394 KLBS ROTARY RPM 80 @ 3825' 0 @ 3911' 70.9 0 RPM PUMP PRESSURE 2005 @ 4237' 1270 @ 2968' 1673.3 1727.06006 PSI DRILLING MUD REPORT DEPTH 4268' MW 9.22 VIS 55 PV 11 YIP 16 FL 4.2 Gels 5!7/10 CL- 3300 FC 1/2 SOL 3.8 SD 0.25 OIL - MBL 1.5 pH 10.6 Ca. 40 CCI 1.10 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 651 @ 3816' 6 @ 4311' 112.8 TRIP GAS 0 CUTTING GAS 0 @ 4335' 0 @ 4335' 0.0 WIPER GAS 383u CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 110605 @ 3818' 1222 @ 4335' 20094.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 4335' 0 @ 4335' 0.0 AVG 0 PROPANE (C-3) 0 @ 4335' 0 @ 4335' 0.0 CURRENT 34u BUTANE(C4) 0 @ 4335' 0 @ 4335' 0.0 CURRENT BACKGROUND/AVG 8u/30u PENTANE (C-5) 0 @ 4335' 0 @ 4335' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY 50% Tuffaceous Claystone, 30% Sand, 20% Tuffarceous Siltstone DAILY ACTIVITY Continued drilling from 2715' to 3465', picked up, circulated sweep, and pulled out of the hole from 3465'to 2406' forwiper top. Serviced SUMMARY rig and ran back into the hole from 2406' to 3465'. Continued dolling from 3495' to 4335', pumping sweeps when needed. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 ��IV REPORT FOR Clint Montague, Adam Dorr DATE Jun 14, 2017 DEPTH 5452' PRESENT OPERATION Circulating before wiper trip TIME 23:59:59 YESTERDAY 4335' 24 HOUR FOOTAGE 1117' CASING INFORMATION 16" @ 138' 7 5/8" @ 1419' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5415.68' 35.23 346.27 4607.32' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Varel V513PDHRU 4008283 4x9, 3x10 1423' 4029' 2912 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 214.0 @ 4473' 18.4 @ 5226' 140.0 143.270 FT/HR SURFACETORQUE 10098 @ 5422' 0 @ 5219' 7385.3 9854.64648 AMPS WEIGHT ON BIT 9 @ 5101' 0 @ 4337' 4.9 7.81558 KLBS ROTARY RPM 80 @ 4996' 0 @ 5273' 61.0 77.20 RPM PUMP PRESSURE 2358 @ 5422' 1592 @ 4459' 2042.9 2271.95996 PSI DRILLING MUD REPORT DEPTH 5452' MW 9.35 VIS 56 PV 14 YP 16 FL 3.9 Gels 5/9/14 CL- 33000 FC 1/2 SOL 5.0 SD 0.30 OIL - MBL 3.0 pH 10.3 Ca+ 40 CCI 0.70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1227 @ 4637' 11 @ 4335' 156.0 TRIP GAS 0 CUTTING GAS 0 @ 5452' 0 @ 5452' 0.0 WIPER GAS 542u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 194661 @ 4639' 1371 @ 4460' 27226.1 CONNECTION GAS HIGH 0 ETHANE (C4) 0 @ 5452' 0 @ 5452' 0.0 AVG 0 PROPANE (C-3) 9 @ 5284' 9 @ 5285' 0.0 CURRENT 42u BUTANE (C-4) 0 @ 5452' 0 @ 5452' 0.0 CURRENT BACKGROUND/AVG 25u/20u PENTANE (C-5) 0 @ 5452' 0 @ 5452' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY 40% Tuffaceous Sikstone, 30% Sand, 20% Tuffaceous Sandstone, 10% Tuffaceous Claystone Continue drilling ahead from 4335' to 4458', pick up, circulate, pump sweep and pull out of hole from 4458'to 1410' for wiper trip. Service DAILYACTIVITY rig and run back into hole from 1410' to 4458'. Drill ahead from 4458' to 5452', circulate, pump sweep, and prepare to pull out of hole for SUMMARY wiper trip. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilichik Unit DAILY WELLSITE REPORT Kalotsa ��,wVlR CA 3 -� \IG REPORT FOR Clint Montague, Adam Dorr DATE Jun 15, 2017 DEPTH 6450' PRESENT OPERATION Wiper Trip TIME 23:59:59 YESTERDAY 5452' 24 HOUR FOOTAGE 998' CASING INFORMATION 16p'@ 138' 7 5/8" @ 1419' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6416.75' 33.60 345.16 5438.61' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Varel V513PDHRU 4008283 4x9, 3x10 1423' 5027' 37:00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 184.8 @ 5894' 11.2 @ 5581' 135.9 148.70 FT/HR SURFACETORQUE 11400 @ 6416' 0 @ 5957' 9118.0 11037.92074 AMPS WEIGHT ON BIT 9 @ 5626' 0 @ 6397' 4.6 5.26956 KLBS ROTARY RPM 79 @ 5909' 0 @ 6399' 66.6 76.690 RPM PUMP PRESSURE 2703 @ 6435' 2000 @ 5764' 2396.1 2597.10 PSI DRILLING MUD REPORT DEPTH 6450' MW 9.3 VIS 54 PV 12 YP 18 FL 3.9 Gels 5/11/15 CL- 34500 FC 1/2 SOL 4.5 SO 0.25 OIL 0/92.7 MBL 3.5 pH 10.6 Ca+ 40 CCI 0.75 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1800 @ 5565' 21 @ 6138' 207.6 TRIP GAS 0 CUTTING GAS 0 @ 6450' 0 @ 6450' 0.0 WIPER GAS 554u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 268890 @ 5567' 1168 @ 5732' 35147.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 6450' 0 @ 6450' 0.0 AVG 0 PROPANE (C-3) 0 @ 6450' 0 @ 6450' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 6450' 0 @ 6450' 0.0 CURRENT BACKGROUND/AVG0 PENTANE (CS) 0 @ 6450' 0 @ 6450' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY Tuffaceous Sandstone, Tuffaceous Siltstone, Tuffaceous Claystone, Sand, Coal, Tuff, Carbonaceous shale DAILY ACTIVITY Pulled out of the hole from 5452'to 4397', serviced rig, and ran back into the hole from 4397'to 5452'. Drilled ahead from 5452' to 6450'. SUMMARY pumping sweeps when needed. Picked up, circulated, pumped a sweep, and pulled out of the hole from 6450' to 5445' for a wiper trip. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa CANy'n�. 3 \'G REPORT FOR Clint Montague, Adam Dorr DATE Jun 16, 2017 DEPTH 7500' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 6450' 24 HOUR FOOTAGE 1050' CASING INFORMATION 16" @ 138' 7 5/8" @ 1419' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEYDATA 7414.40' 15.08 347.74 6337.56' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Varel V513PDHRU 4008283 4x9, 3x10 1423' 6077' 4553 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 214.3 @ 6786' 23.4 @ 7212' 131.8 117.690 FT/HR SURFACE TORQUE 13071 @ 7466' 0 @ 7454' 10171.5 12372.25879 AMPS WEIGHT ON BIT 10 @ 6958' 0 @ 6453' 5.2 7.06355 KI -BS ROTARY RPM 79 @ 6583' 1 @ 6772' 65.4 73.930 RPM PUMP PRESSURE 2984 @ 7376' 1936 @ 7015' 2628.1 2860.11011 PSI DRILLING MUD REPORT DEPTH 7448' MW 9.6 VIS 54 PV 13 YP 19 FL 3.8 Gels 6/13/20 CL- 33000 FC 1/2 SOL 5.8 SO 0.20 OIL - MBL 4.0 pH 10.3 Ca+ 40 CCI 0.70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 879 @ 6562' 14 @ 6746' 128.7 TRIP GAS 0 CUTTING GAS 0 @ 7500' 0 @ 7500' 0.0 WIPER GAS 3113u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 144050 @ 6563' 1913 @ 6804' 22479.7 CONNECTION GAS HIGH 152u ETHANE (C-2) 0 @ 7500' 0 @ 7500' 0.0 AVG 35u PROPANE (C-3) 15 @ 6563' 9 @ 7407' 0.4 CURRENT 91u BUTANE (C-4) 0 @ 7500' 0 @ 7500' 0.0 CURRENT BACKGROUND/AVG 28u/20u PENTANE (C-5) 0 @ 7500' 0 @ 7500' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY tuffaceous Siltstone, Tuffaceous Sandstone, Sand, Coal DAILY ACTIVITY Ran back into the hole from 5445' to 6450', circulated, and drilled ahead to 7448'. Circulated at 7448', pumped sweep, and pulled out of SUMMARY hole to 6391' for a wiper trip. Ran back into the hole from 6391'to 7448' and drill ahead to 7500'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 C©VR / REPORT FOR Clint Montague, Adam Dorr DATE Jun 17, 2017 DEPTH 7824' PRESENT OPERATION Circulating and weight up mud TIME 23:59:59 YESTERDAY 7500' 24 HOUR FOOTAGE 324' CASING INFORMATION 16" @ 138' 7 5/8" @ 1419" Circulate and weight up mud DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEYDATA 7725.45' 8.97 352.17 6642.57' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Varel V513PDHRU 4008283 4x9, 3x10 1423' 6401' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 183.8 @ 7602' 12.5 @ 7519' 99.5 107.030 FT/HR SURFACETOROUE 13429 @ 7718' 0 @ 7707' 11756.0 12964.4460 AMPS WEIGHT ON BIT 8 @ 7505' 1 @ 7635' 4.4 5.20400 KLBS ROTARY RPM 76 @ 7775' 0 @ 7708' 68.1 75.560 RPM PUMP PRESSURE 2993 @ 7564' 2568 @ 7513' 2862.4 2879.860 PSI DRILLING MUD REPORT DEPTH 7824' MW 9.7 VIS 54 PV 13 YP 19 FL 3.6 Gels 5/10/14 CL- 32000 FC 1/2 SOL 6.3 SD 0.20 OIL - MBL 4.0 pH 10.6 Ca- 40 CCI 0.70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 654 @ 7572' 13 @ 7790' 157.9 TRIP GAS 0 CUTTING GAS 0 @ 7824' 0 @ 7824' 0.0 WIPER GAS 3528u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 110354 @ 7574' 2540 @ 7791' 25905.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 7824' 0 @ 7824' 0.0 AVG 0 PROPANE (C-3) 14 @ 7574' 9 @ 7787' 0.5 CURRENT 17u BUTANE (C-4) 0 @ 7824' 0 @ 7824' 0.0 CURRENT BACKGROUND/AVG 16u/1 9u PENTANE (C-5) 0 @ 7824' 0 @ 7824' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY Tuffaceous Siltstone, Tuffaceous Sandstone, Sand DAILY ACTIVITY Drilled ahead from 7500' to 7576, trouble shoot MWD tools, and continued drilling from 7575'to 7824'. Decided to pull out of the hole to SUMMARY change MWD tools. Picked up, Circulated, and pulled out of the hole from 7824'to 4224'. Due to swabbing with high gas we ran back into the hole from 4224'to 7824', circulated, weighted up mud, and prepared to pull back out of the hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 CANa■y'��J. \'G REPORT FOR Clint Montague, Adam Dor, DATE Jun 18, 2017 DEPTH 7824' PRESENT OPERATION Running into the hole TIME 23:59:59 YESTERDAY 7824' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5l8" @ 1419' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" Varel V513PDHRU 4008283 4x9, 3x10 1423' 7824' 6401' 49.53 2-4-DL-A-X-1-BT-DSF Tool Failure 4 6.75" HDBS MM65D 12396253 6x10 7824' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7824' MW 9.8 VIS 57 PV 13 YP 17 FL 3.9 Gels 6/9/14 CL- 32000 FC 1/2 SOL 6.5 SO 0.20 OIL - MBL 4.0 pH 10.7 Ca+ 40 CCI 0.70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 55u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE(CA) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Pulled out of the hole from 7824'to surface, removed sources, and downloaded tool. Picked up new motor, bit, and MWD tool. SUMMARY Downloaded MWD tools and performed a shallow pulse test. Made up BHA and ran into the hole to 4830'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Nmilchik Unit DAILY WELLSITE REPORT Kalotsa 3 CMRIG REPORT FOR Clint Montague, Adam Dorr DATE Jun 19, 2017 DEPTH 8783' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 7824' 24 HOUR FOOTAGE 959' CASING INFORMATION 16" @ 138' 7 5/8" @ 1419' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8787.89' 6.09 349.92 7697.76' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.75" HDBS MM65D 12396253 6x10 7824' 959' 13:01 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 150.4 @ 7906' 12.4 @ 8388' 86.7 85.940 FT/HR SURFACE TORQUE 16847 @ 8783' 0 @ 7891' 13373.7 16847.14648 AMPS WEIGHT ON BIT 12 @ 8587' 0 @ 7890' 7.4 5.11638 KLBS ROTARY RPM 77 @ 7952' 0 @ 7898' 66.1 72.520 RPM PUMP PRESSURE 2879 @ 7824' 1550 @ 7825' 1828.2 1995.02002 PSI DRILLING MUD REPORT DEPTH 8772' MW 9.8 VIS 51 PV 14 YP 17 FL 3.8 Gels 5/10/13 CL- 34000 FC 1/2 SOL 6.3 SO 0.20 OIL - MBL 3.5 pH 10.5 Ca. 40 CCI 1.20 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 389 @ 8690' 16 @ 7968' 79.0 TRIP GAS 0 CUTTING GAS 0 @ 8783' 0 @ 8783' 0.0 WIPER GAS 691u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 68621 @ 8691' 2461 @ 7969' 13932.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 8783' 0 @ 8783' 0.0 AVG 0 PROPANE (C-3) 14 @ 8691' 9 @ 8472' 0.8 CURRENT 25u BUTANE (C-4) 0 @ 8783' 0 @ 8783' 0.0 CURRENT BACKGROUND/AVG 25u/20u PENTANE (C-5) 0 @ 8783' 0 @ 8783' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY Tuffaceous Sandstone, Tuffaceous Siltstone, Sand DAILY ACTIVITY Continued running into the hole from 4830' to 7824'. Drilled ahead to from 7824' to 8783' circulating and pumping sweeps when SUMMARY needed. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa3 /i^ {A.�,�V■■j'f�'��J CMRIG -. \IG REPORT FOR Clint Montague, Adam Dorr DATE Jun 20, 2017 DEPTH 9265' PRESENT OPERATION POOH TIME 23:59:59 YESTERDAY 8783' 24 HOUR FOOTAGE 482' CASING INFORMATION --- 16" @ 138' `"-- 7 5/8" @ 1419' --- 41/2" Prod Csg @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEYDATA 9265.0 3.58 348.05 8173.25 BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6 3/4" MOBS MM65D 12396253 6x-10 7824' 9265' 1441' 17.73 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 203.0 @ 9097' 33.0 @ 8871' 105.2 140.3 FT/HR SURFACE TORQUE 17274 @ 9186' 15394 @ 8867' 16535.4 17210.1 AMPS WEIGHT ON BIT 10 @ 8907' 3 @ 9262' 8.3 9.4 KLBS ROTARY RPM 74 @ 8955' 68 @ 8846' 72.0 73.7 RPM PUMP PRESSURE 2189 @ 9151' 1814 @ 8825' 2076.2 2135.7 PSI DRILLING MUD REPORT DEPTH 8772' MW 9.8 VIS 51 PV 14 YP 16 FL 3.8 Gels 5/10/13 CL- 34000 FC 1/2 SOL 6.3 SO 0.2 OIL .0/91.0 MBL 3.5 pH 10.5 Ca+ 40 CCI 1.20 MWD SUMMARY INTERVAL Geo-Prog TO TO TOOLS MWD, Mudmolor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 487 @ 9103' 15 @ 8949' 80.0 VIPER GAS @ 7531' = 146u TRIP GAS @ 9260' = 394U CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 86596 @ 9105' 2446 @ 8949' 14445.5 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 17 @ 9105' 9 @ 9037' 8.6 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG lu PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT Medium dark gray Tuffaceous sediments, moderately sorted, subangular to subround clast, common loose unconsolidated sand grains, LITHOLOGY trace to slightly camoneceous, thin to moderately thick coal seams throughout interval. DAILY ACTIVITY Continue to drill ahead to TO at 9265', Circulate sweep, Wipe hole to 7515', back ream as needed, Circulate bottoms up, max gas of 146u, SUMMARY Trip in the hole to 9260', Circulate bottoms up, max gas of 394u, POOH from 9260', pump out of hole from 9260'to 8945', Flow check, Continue to POOH CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.0 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa /iw �u RIG 3 -,�V■■ �I1 REPORT FOR: Rance Pederson, Adam Dort DATE Jun 21, 2017 DEPTH 9265' PRESENT OPERATION RUN E-LOGS TIME 23:59:59 YESTERDAY 9265' 24 HOUR FOOTAGE 0' CASING INFORMATION ---- 16" @ 138' --- 7 5/8" fig 1419' '--* 4 1/2" Prod Csg @ x xx' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9265.0 3.58 348.05 8173.25 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6 3/4" MDBS MM65D 12396253 6x-10 7824' 9265' 1441' 17.73 I-I-ER-G-X-1-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 0 @ 9265' 0 @ 9265' 0 0 FT/HR SURFACETORQUE 0 @ 9265' 0 @ 9265' 0 0 FT/LBS WEIGHT ON BIT 0 @ 9265' 0 @ 9265' 0 0 KLBS ROTARY RPM 0 @ 9265' 0 @ 9265' 0 0 RPM PUMP PRESSURE 0 @ 9265' 0 @ 9265' 0 0 PSI DRILLING MUD REPORT DEPTH 9265' MW 9.8 VIS 50 PV 14 YP 17 FL 3.6 Gels 5/8/13 CL- 33000 FC 1/2 SOL 6.4 SD 0.2 OIL .0/91.0 MBT 4.3 pH 10.2 Ca+ 40 ALK Mud 1.10 MWD SUMMARY INTERVAL 4800 TO ? TOOLS Schlumberger XPT Wreline tool GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 @ 9265' 1 @ 9265' lu TRIP GAS WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 1u PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation @ 9265' TD PRESENT Medium dark gray Tuffaceous sediments, moderately sorted, subangular to subround Gast, common loose unconsolidated sand grains, LITHOLOGY trace to slightly carboneceous, thin to moderately thick coal seams throughout interval. DAILY ACTIVITY Continue to POOH, UD BHA and Halliburton tools, M/U clean out BHA, hold PJSM w/Schlumberger loggers, Rig up wire line drift log tool, SUMMARY RIH, tight @ 4870', Rig down drift tool, Run XPT tool, tool not getting readings, Laydown XPT, Run new XPT tool, Hit bridge @ 4870', Wreline from 8900' TO 8152', Continue with XPT Wreline operation. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.0 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa C.MR' 3 V,/w� REPORT FOR: Rance Pederson, Adam Dort DATE Jun 22, 2017 DEPTH 9265' PRESENT OPERATION RUN E-LOGS TIME 23:59:59 YESTERDAY 9265' 24 HOUR FOOTAGE 0' CASING INFORMATION ---16" @ 138' . -'- 7 5/8"@ 1419' ---* 4 1/2" Prod. Csg @ xxxx' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9265.0 3.58 348.05 8173.25 BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6 3/4" MOBS MM65D 12396253 6x-10 7824' 9265' 1441' 17.73 I-I-ER-G-X4-NO-TD TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 0 @ 9265' 0 @ 9265' 0 0 FT/HR SURFACE TORQUE 0 @ 9265' 0 @ 9265' 0 0 FT/LBS WEIGHT ON BIT 0 @ 9265' 0 @ 9265' 0 0 KLBS ROTARY RPM 0 @ 9265' 0 @ 9265' 0 0 RPM PUMP PRESSURE 0 @ 9265' 0 @ 9265' 0 0 PSI DRILLING MUD REPORT DEPTH 9265' MW 9.8 VIS 50 PV 14 YP 17 FL 3.6 Gels 5/8/13 CL- 33000 FC 1/2 SOL 6.4 SO 0.2 OIL .0/91.0 MBT 4.3 pH 10.2 Ca+ 40 ALK Mud 1.10 SCHLUMBERGER E-LOG SUMMARY INTERVAL 6480' TO XXXX? TOOLS Schlumberger Triple Combo W reline tool GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 @ 9265' 1 @ 9265' 1u TRIP GAS WIPER GAS CHROMATOGRAPHY (Ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 1u PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation @ 9265' TD PRESENT Medium dark gray Tuffaceous sediments, moderately sorted subangular to subround clast, common loose unconsolidated sand grains, LITHOLOGY trace to slightly carboneceous, thin to moderately thick coal seams throughout interval. DAILY ACTIVITY Continue with Wireline operations from 4320' to 2378', Service rig, monitorwell, Finish up the XPT wireline run, Layout XPT tool, Pick up SUMMARY SWC tool, Run in hole, Bridge @ 6480'. Start coring @ 6426'to 1560', Service Rig, POOH & Lay down SWC tool, RIH with Triple Combo tool to 6480'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.0 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Nimlchik Unit DAILY WELLSITE REPORT Kalotsa ////�� ■\/�� CANRI 3 V REPORT FOR: Rance Pederson, Adam Dort DATE Jun 23, 2017 DEPTH 9265' PRESENT OPERATION RUN E-LOGS TIME 23:59:59 YESTERDAY 9265' 24 HOUR FOOTAGE 0' CASING INFORMATION ---16" @ 138' --'- 7 5/8" @ 1419' ---* 4 1/2" Prod. Csg @ xxxx' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9265.0 3.58 348.05 8173.25 BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6314" MOBS MM65D 12396253 6x-10 7824' 9265' 1441' 17.73 I-1-ER-G-X-I-NO-TD TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 0 @ 9265' 0 @ 9265' 0 0 FT/HR SURFACETORQUE 0 @ 9265' 0 @ 9265' 0 0 FT/LBS WEIGHT ON BIT 0 @ 9265' 0 @ 9265' 0 0 KLBS ROTARY RPM 0 @ 9265' 0 @ 9265' 0 0 RPM PUMP PRESSURE 0 @ 9265' 0 @ 9265' 0 0 PSI DRILLING MUD REPORT DEPTH 9265' MW 9.8 VIS 50 PV 15 YP 17 FL 3.6 Gels 5/7/11 CL- 33000 FC 1/2 SOL 6.4 SO 0.2 OIL .0/91.0 MBT 4.3 pH 10.3 Ca- 40 ALK Mud 1.00 SCHLUMBERGER E-LOG SUMMARY INTERVAL 5828' TO 14191 TOOLS Schlumberger PNX Wrehne tool GAS SUMMARY (units) HIGH LOW AVERAGE CIRCULATING GAS @ @ to TRIP GAS WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 1u PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation @ 9265' TD PRESENT Medium dark gray Tuffaceous sediments, moderately sorted, subangular to subround Gast, common loose unconsolidated sand grains, LITHOLOGY trace to slightly carboneceous, thin to moderately thick coal seams throughout interval. DAILY ACTIVITY Continue logging with Triple Combo tool from 6480', Service Rig, POOH with tool, Layout hanger and RA Sources, Pick up SWC tool, Run in SUMMARY the hole with SWC, Layout SWC tool because tool jammed up again, Layout SWC tool, Pick up PNX tool, Run in hole to bridged out @ 6480', Logging from 6480'to 5828', Logging with PNX from 5828'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.0 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT �1 \IG Kalolsa 3 REPORT FOR: Rance Pederson, Adam Dom DATE Jun 24, 2017 DEPTH 9265' PRESENT OPERATION: POOH TIME 23:59:59 YESTERDAY 9265' 24 HOUR FOOTAGE 0' CASING INFORMATION ---16" @ 138' --'- 7 5/8" @ 1419' '--* 4 1/2" Prod. Csg @ xxxx' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9265.0 3.58 348.05 8173.25 BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 63/4" MDBS MM65D 12396253 6x-10 7824' 9265' 1441' 17.73 I-I-ER-G-X-I-NO-TD TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 0 @ 9265' 0 @ 9265' 0 0 FT/HR SURFACE TORQUE 0 @ 9265' 0 @ 9265' 0 0 FT/LBS WEIGHT ON BIT 0 @ 9265' 0 @ 9265' 0 0 KLBS ROTARY RPM 0 @ 9265' 0 @ 9265' 0 0 RPM PUMP PRESSURE 0 @ 9265' 0 @ 9265' 0 0 PSI DRILLING MUD REPORT DEPTH 9265' MW 9.85 VIS 50 PV 14 YP 16 FL 4.2 Gels 5/7/11 CL- 32000 FC 1/2 SOL 6.8 SD 0.2 OIL .0/91.0 MBT 4.2 pH 10.4 Ca+ 40 ALK Mud 1.10 SCHLUMBERGER wireline summary INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE CIRCULATING GAS 3490u @ 8998' 36u @ 3241' 1763u TRIP GAS @ 8998' = 3490u WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 1u PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation @ 9265' TD PRESENT Medium dark gray Tuffaceous sediments, moderately sorted, subangular to subround Bast, common loose unconsolidated sand grains, LITHOLOGY trace to slightly carboneceous, thin to moderately thick coal seams throughout interval. Continue logging PNX from 5828' to 1419', W-M. POOH from 1419' to surface. Lay down logging tools Rig down Schlumberger logging DAILY equipment, Service Top Drive, Service Rig, P/U clean out BHA, TIH to 1307', fill pipe circulate bottoms up,Max Gas Bu, Slip and Cut 120' drilling ACTIVITY line, TIH from 1307' to 2247', filling pipe every 15 stands,Circulate @3241', Max Gas 36u, Stag in hole, Circulate BU@6352', Max Gas 808u, SUMMARY Circulate BU@8784', Max Gas 1435u, Circulate BU@8998', Max Gas 3491 u, Continue to RIH to bottom, Circulate Sweep @9265, Circulate clean, Rack back 5 stands in Derrick, flow check, pump dryjob @ 8904', POOH laying down drill pipe from 8904' to 5277'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.0 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 3 � r�l� REPORT FOR: Rance Pederson, Adam Dorf DATE Jun 25, 2017 DEPTH 9265' PRESENT OPERATION: RIH 4.5 Production Csg String TIME 23:59:59 YESTERDAY 9265' 24 HOUR FOOTAGE 0' CASING INFORMATION --- 16" @ 138' ""'""" 7 5/8" @ 1419' ----*4 1/2" Prod. Csg @ xxxx' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9265.0 3.58 348.05 8173.25 BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6 3/4" MOBS MM65D 12396253 6x-10 7824' 9265' 1441' 17.73 I -I -ER -G -X -I -NO -TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 0 @ 0 @ 0 0 FT/HR SURFACETORQUE 0 @ 0 @ 0 0 FT/LBS WEIGHT ON BIT 0 @ 0 @ 0 0 KLBS ROTARY RPM 0 @ 0 @ 0 0 RPM PUMP PRESSURE 0 @ 0 @ 0 0 PSI DRILLING MUD REPORT DEPTH 9265' MW 9.85 VIS 50 PV 14 YP 16 FL 4.2 Gels 5/7/11 CL- 32000 FC 1/2 SOL 6.8 SO 0.2 OIL .0/91.0 MBT 4.2 pH 10.4 Ca- 40 ALK Mud 1.10 SCHLUMBERGER wireline summary INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE CIRCULATING GAS 38u @ 2985' 3u @ 1325' 25u TRIP GAS WIPER GAS CHROMATOGRAPHY ppm) SURVEY METHANE (C-1) 0 @ @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ @ 0.0 AVG PROPANE (C-3) 0 @ @ 0.0 CURRENT BUTANE (C-4) 0 @ @ 0.0 CURRENT BACKGROUND/AVG 38u PENTANE (C-5) 0 @ @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation @ 9265' TD PRESENT Medium dark gray Tuffaceous sediments, moderately sorted, subangular to subround clast, common loose unconsolidated sand grains, LITHOLOGY trace to slightly carboneceous, thin to moderately thick coal seams throughout intervel. DAILY POOH laying down drill pipe from 5277', Continue laying down drill pipe from 5277'to 4586', pulled 40K over, reamed tight spot @ 4586', ACTIVITY circulate bottoms up, Continue laying down D.P. to 378', TIH from 378' to 944', Lay down D.P. to 0'. PREPARE for Shell BOPE test, BOPE test SUMMARY complete, Pull test plug, Run hanger, Rig up casing equipment, P/U & M/U float equipment, test float equipment, begin running in hole 4.5 production casing to 2985'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.0 REPORT BY Marquel Mosebay DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS REQUIRED INFORMATION ,��' O!� � Mud Log Samples �! @' DATA INFORMATION Current Status 1 -GAS API No. 50-133-20661-00-00 UIC No Directional Survey Yes Types Electric or Other Logs Run: ROP-DGR-EWR-CTN-ALD, ECS -GR, HNGS-GR, PNX-GR, PNX-PBM (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media _ No Start Stop Cry Received Comments ED C 28420 Digital Data 10 9350 7/19/2017 Electronic Data Set, Filename: Kalotsa 3.las__ _ ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa3.dbf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa3.mdx ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa3_SCL.DBF ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa3_SCL.MDX ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa3_tvd.dbf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa3_tvd.mdx ED C 28420 Digital Data 7/19/2017 Electronic File: kalotsa3.hdr ED C 28420 Digital Data 7/19/2017 Electronic File: kalotsa3r.dbf ED C 28420 Digital Data 7/19/2017 Electronic File: kalotsa3r.mdx ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-07-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-08-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-09-2017 AM Report.pdf. ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-10-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-11-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-12-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-13-2017 AM Report.pdf AOGCC Page 1 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator NILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-142017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-15-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-16-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-17-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-18-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-19-2017 AM Reporl.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-20-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-21-2017 AM Report.pdf ED C 28420 Digital. Data 7/19/2017 Electronic File: Kalosta #3 06-22-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-23-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-24-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalosta #3 06-25-2017 AM Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Final Well Report.docx ED C 28420 Digital Data P 7/19/2017 Electronic File: Kalotsa 3 Final Well Report.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - 5in Formation Log (� MD.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - 5in Formation Log p TVD.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - Drilling Dynamics. p Y Log MD.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - Drilling Dynamics P Log TVD.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - Formation Log MD.pdf AOGCC Page 2 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - Formation Log • P TVD.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - Gas Ratio Log P MO.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - Gas Ratio Log ' TVD.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: KALOTSA 3 - LW D Combo Log P MD.pdf ED C 28420 Digital Data Electronic File: KALOTSA 3 - LW D Combo Log p7/19/2017 i TVD.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - 5in Formation Log MD.tif ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Sin Formation Log TVD.tif ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Drilling Dynamics Log MD.tif ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Drilling Dynamics Log TVD.tif ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Formation Log MD.tif , ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Formation Log TVD.tif , ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Gas Ratio Log MD.tif , ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Gas Ratio Log TVD.tif ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - LW D Combo Log MD.tif ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - LW D Combo Log WWI ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 1.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 1.xls ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 2.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 2.xls ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 3.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 3.xls ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 4.pdf AOGCC Page 3 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00.00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28420 Digital Data 7/19!2017 Electronic File: Kalotsa 3 Show Report 4.xls ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 5.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 5.xls ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 6.pdf ED C 28420 Digital Data - 7/19/2017 Electronic File: Kalotsa 3 Show Report 6.xls ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 7.pdf ED C 28420 Digital Data 7/19/2017 Electronic File: Kalotsa 3 Show Report 7.xis Log C 28420 Log Header Scans 0 0 2170280 KALOTSA 3 LOG HEADERS Log C 28421 Log Header Scans 0 0 2170280 KALOTSA 3 LOG HEADERS ED C 28421 Digital Data 50 9266 7/19/2017 Electronic Data Set, Filename: Kalotsa #3 DGR_EWR_ALD ED C 28421 Digital Data 7/19/2017 _CTN.las Electronic File: Kalotsa 3_DGR_EWR_ALD_CTN MD.cgm ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3_DGR_EWR_ALD_CTN TVD.cgm ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Definitive Suwey.pdf ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3 - Definitive Surveys.txt ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3_DGR_EWR_ALD CTN' MD.emf ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3_DGR_EWR_ALD CTN' TVD.emf ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3_DGR_EWR_ALD CTN P MD.pdf ED C 28421 Digital Data 19/2017 Electronic File: Kalotsa 3_DGR_EWR_ALD_CTN ' TVD.pdf ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3_DGR_EWR_ALD_CTN MD.tif ED C 28421 Digital Data 7/19/2017 Electronic File: Kalotsa 3_DGR_EWR_ALD_CTN. TVD.tif ED C 28422 Digital Data 1354 6497 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa3_MAI N_ConCu_R06_L003Up_P, NX_PSTP.las AOGCC Page 4 of I7— — Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12115/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS LIC No ED C 28422 Digital Data 1885 2153 7/19/2017 Electronic Data Set, Filename: Hiloorp_Kalotsa3_REPEAT_ConC u_R06_L004U p_PNX_PSTP.las " ED C 28422 Digital Data 7/19/2017 Electronic File: Hiloorp_Kalotsa3_MAI N_ConCu_R06_L003Up_P NX_PSTP.dlis ED C 28422 Digital Data 7/19/2017 Electronic File: Hilcorp_Kalotsa3_REPEAT_ConCu_R06_L004U p_PNX_PSTP.dlis ED C 28422 Digital Data 7/19/2017 Electronic File: Hilcory_Kolatsa3_PNX- 17 GR_24Junl7_FINAL.Pdf Log C 28422 Log Header Scans 0 0 2170280 KALOTSA 3 LOG HEADERS Log C 28423 Log Header Scans 0 0 2170280 KALOTSA 3 LOG HEADERS ED C 28423 Digital Data 264 9158 12/15/2017 Electronic Data Set, Filename: Hilcorp_Kolatsa3_PNX- , G R_9Ju117_ConCu_Main.las ED C 28423 Digital Data 4160 4535 12/15/2017 Electronic Data Set, Filename: Hilcorp_Kolatsa3_PNX- GR_9Jul17_ConCu_Repeat1_4500ft.las . ED C 28423 Digital Data 5456 5735 12/15/2017 Electronic Data Set, Filename: Hilcorp_Kolatsa3_PNX- G R_9Ju117_ConCu_Repeatl ED C 28423 Digital Data 4156 4535 12/15/2017 _5700ft.las Electronic Data Set, Filename: Hilcorp_Kolatsa3_PNX- GR_9Ju117_ConCu_Repeat2_4500ft.las - ED C 28423 Digital Data 5456 5735 12/15/2017 Electronic Data Set, Filename: Hilcorp_Kolatsa3 PNX- GR_9JuIt 7_ConCu_Repeat2_5700ft.las ED C 28423 Digital Data 12/15/2017 Electronic File: DLIS Data.zip , ED C 28423 Digital Data 12/15/2017 Electronic File: LAS Data.zip ED C 28423 Digital Data 12/15/2017 Electronic File: Hilcorp_Kolatsa3_PNX- GR_9Ju117_ConCu_MainAlis ED C 28423 Digital Data 12/15/2017 Electronic File: Hiloorp_Kolatsa3_PNX- GR_9J ul17_ConCu_Repeat t _4500ft.dlis ED C 28423 Digital Data 12/15/2017 Electronic File: Hilcorp_Kolatsa3_PNX- GR_9Jul17_ConCu_Repeatl_5700ft.dlis - AOGCC Page 5 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 MD 9265 TVD 8173 Completion Date 7/27/2017 ED C 28423 Digital Data ED C 28423 Digital Data ED C 28423 Digital Data Log C 28424 Log Header Scans ED C 28424 Digital Data ED C 28424 Digital Data ED C 28424 Digital Data ED C 28424 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C A0GCC 28424 Digital Data 28424 Digital Data 28425 Digital Data 28425 Digital Data 28425 Digital Data 28425 Digital Data 28425 Digital Data 28425 Digital Data 28425 Digital Data Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 Completion Status 1 -GAS Current Status 1 -GAS UIC No 12/15/2017 Electronic File: Hilcorp_Kolatsa3_PNX- GR_9Ju117_ConCu_Repeat2_4500ft.dlis 12/15/2017 Electronic File: Hilcorp_Kolatsa3 PNX- GR_9Ju117_ConCu_Repeat2_5700ft.dlis 1712/15/2017 Electronic File: Hilcorp_Kolatsa3_PNX- GR_9Ju117_F I NAL.Pdf 0 0 2170280 KALOTSA 3 LOG HEADERS 1330 6494 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa3_MAIN _ConCu_R04_L005Up_E CS_LDSC_H NGC_HN GS.las 2131 2407 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa3 REPEAT ConCu_R04_L006U - p_ECS_LDSC_HNGC_HNGS.Ias 7/19/2017 Electronic File: Hilcorp_Kalotsa3_MAIN _ConCu_R04_L005Up_E CS_LDSC_HNGC_HNGS.dlis 7/19/2017 Electronic File: Hilcorp_Kalotsa3_REPEAT _CConCu_R04_L006 Up_ECS_LDSC_HNGC_HNGS.dlis 19/2017 Electronic File: Y Hilcorp_Kal0sta3_ECS_23Jun17_FINAL.Pdf 7/19/2017 Electronic File: P Hilcorp_Kalosta3_HNGS_23Junl7_FINAL.Pdf ' 0 625 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta003_XPT.Ias 0 442 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta004_XPT.Ias 0 404 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta005_XPT.las 0 249 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta006_XPT.Ias 0 433 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta007_XPT.las 0 223 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta008_XPT.Ias 0 273 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta009_XPT.Ias Page 6 al' 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00.00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28425 Digital Data 0 507 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta010_XPT.las ED C 28425 Digital Data 0 415 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta011_XPT.las ED C 28425 Digital Data 0 701 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta012_XPT.las ED C 28425 Digital Data 0 936 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta013_XPT.las ED C 28425 Digital Data 0 780 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta014_XPT.las ED C 28425 Digital Data 0 637 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta015_XPT.Ias ED C 28425 Digital Data 0 1539 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta016_XPT.las ED C 28425 Digital Data 0 436 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta017_XPT.las ED C 28425 Digital Data 0 488 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta018_XPT.las ED C 28425 Digital Data 0 178 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta019_XPT.las 0 346 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta020_XPT.las ED C 28425 Digital Data 0 880 7/19/2017 Electronic Data Set, Filename: ConC u_R02_Sta021 ED C 28425 Digital Data 0 473 7/19/2017 _XPT.las Electronic Data Set, Filename: ConCu_R02_Sta022_XPT.las ED C 28425 Digital Data 0 193 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta023_XPT.Ias ED C 28425 Digital Data 0 207 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta024_XPT.las ED C 28425 Digital Data 0 379 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta025_XPT.las ED C 28425 Digital Data 0 232 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta026_XPT.las ED C 28425 Digital Data 0 159 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta027 XPT.las AOGC'C' Page 7 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12115/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/2 712 01 7 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28425 Digital Data 0 1924 7/19/2017 Electronic Date Set, Filename: ConCu_R02_Sta028_XPT.las ED C 28425 Digital Data 0 711 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta029_XPT.las ED C 28425 Digital Data 0 249 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta030_XPT.las ED C 28425 Digital Data 0 293 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO31_XPT.las ED C 28425 Digital Data 0 225 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO32_XPT.las ED C 28425 Digital Data 0 177 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO33_XPT.las ED C 28425 Digital Data 0 304 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO34_XPT.las ED C 28425 Digital Data 0 418 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO35_XPT.las ED C 28425 Digital Data 0 514 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta036_XPT.las ED C 28425 Digital Data 0 451 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO37_XPT.las ED C 28425 Digital Data 0 388 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta038_XPT.las ED C 28425 Digital Data 0 344 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO39_XPT.las ED C 28425 Digital Data 0 687 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta040_XPT.las ED C 28425 Digital Data 0 496 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta041_XPT.las ED C 28425 Digital Data 0 538 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta042_XPT.las ED C 28425 Digital Data 0 521 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta043_XPT.las ED C 28425 Digital Data 0 465 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO44_XPT.las ED C 28425 Digital Data 0 444 7/19/2017 Electronic Data Set, Filename: Co nCu_R02_StaO45_XPT.las AOGCC Page 8 of 17 — _ _ Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C A0G(C Page 9 of 17 hiday. December I5. 2017 28425 Digital Data 0 750 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta046_XPT.las 0 459 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO47_XPT.las 0 433 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta048_XPT.las 0 184 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO49_XPT,Ias 0 220 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta050_XPT.Ias 0 237 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta051_XPT.Ias 0 353 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta052_XPT.Ias 0 577 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta053_XPT.las 0 356 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta054_XPT.las 0 249 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta055_XPT.las 0 268 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta056_XPT.las 0 252 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta057_XPT.las 0 675 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO58_XPT.las 0 543 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCU_R02_StaO59_XPT.las 0 357 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta060_XPT.las 0 475 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_S1a061_XPT.Ias 0 428 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta062_XPT.Ias 0 656 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta063 XPT.las A0G(C Page 9 of 17 hiday. December I5. 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 _ TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C — — —... __ — _. -_ — _ __ ED C 28425 Digital Data 0 863 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO64_XPT.las 0 654 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO65_XPT.las 0 378 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta066_XPT.las 0 270 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta067_XPT.las 0 453 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO68_XPT.las 0 233 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO69_XPT.Ias 0 379 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta070_XPT.las 0 685 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO7l_XPT.las 0 782 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta072_XPT.las 0 325 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta073_XPT.las 0 1233 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO74_XPT.las 0 389 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta075_XPT.las 0 587 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO76_XPT.Ias 0 597 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta077_XPT.las 0 478 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_Sta078_XPT.las 0 445 7/19/2017 Electronic Data Set, Filename: ED C 28425 Digital Data ConCu_R02_StaO79_XPT.las 0 661 7/19/2017 Electronic Data Set, Filename ED C 28425 Digital Data 0 211 ConCu —R02 _StaO80 —XPT.las AOGCC 7/19/2017 Electronic Data Set, Filename: I ConCu R02 Sta081 XPT.las _IVB Page 10 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28425 Digital Data 0 355 7/19/2017 Electronic Data Set, Filename: - ConCu_R02_Sta082_XPT.las ED C 28425 Digital Data 0 774 7/19/2017 Electronic Data Set, Filename: ConCu_R02_StaO83_XPT.las ED C 28425 Digital Data 0 768 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta084_XPT.las ED C 28425 Digital Data 0 390 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta085_XPT.las ED C 28425 Digital Data 0 486 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta086_XPT.las ED C 28425 Digital Data 0 345 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta087_XPT.las ED C 28425 Digital Data 0 829 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta088_XPT.las ED C 28425 Digital Data 0 732 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta089_XPT.las ED C 28425 Digital Data 0 440 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta090_XPT.las ED C 28425 Digital Data 0 648 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta091_XPT.las ED C 28425 Digital Data 0 470 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta092_XPT.las ED C 28425 Digital Data 0 790 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta093_XPT.las ED C 28425 Digital Data 0 1723 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta094_XPT.las ED C 28425 Digital Data 0 631 7/19/2017 Electronic Data Set, Filename: ConCu_R02_Sta095_XPT.las ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta003_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta004_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: C0nCu_R02_Sta005_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta006_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta007_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta008_XPT.this ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta0o9_XPT.dlis AOGCC Page I 1 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50.133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta010_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta011_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta012_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta013_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta014_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta015_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta016_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCuR02_Sta017_XPT.dlis ED C 28425 Digital Data 7/19/2017 _ Electronic File: ConCu_R02_Sta018_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta019_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta020_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta021_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_StaO22_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta023_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_StaO24_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_StaO25_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta026_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta027_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta028_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_StaO29_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta030_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta031_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta032_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta033_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta034_XPTAlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta035_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta036_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02Sta037_XPT.dlis ED C 28425 Digital Data — 7/19/2017 _ Electronic File: ConCu_R02_Sta038_XPT.dlis AOGCC Page 12 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265— TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta039_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta040_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta041_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta042_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta043_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta044_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_StaO45_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta046_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta047_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta048_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta049_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta050_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta051_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_02_StaO52_XPT.dlis R ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta053_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta054_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta055_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta056_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta057_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta058_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta059_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta060_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta061_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta062_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCU_R02_Sta063_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta064_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta065_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta066_XPT.dlis ED C 28425 Digital Data 7/19/2017 Electronic File: ConCu_R02_Sta067_XPT.dlis AOGCC Page 13 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 MD 9265 TVD 8173 ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data ED C 28425 Digital Data AOGCC Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No 7/19/2017 Electronic File: ConCu_R02_Sta068_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta069_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta070_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta071_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta072_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO73_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta074_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_taO75_XPT.dlis S 7/19/2017 Electronic File: ConCu_R02_Sta076_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO77_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO78_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO79_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta080_XPT.dlis 7/19/2017 Electronic Fife: ConCu_R02_Sta081_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta082_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta083_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO84_XPT.diis 7/19/2017 Electronic File: ConCu_R02_Sta085_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta086_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO87_XPT.diis 7/19/2017 Electronic File: ConCu_R02_Sta088_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta089_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO90_XPT.diis 7/19/2017 Electronic File: ConCu_R02_Sta091_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta092_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta093_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_StaO94_XPT.dlis 7/19/2017 Electronic File: ConCu_R02_Sta095_XPT.dlis Page 14 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 MD 9265 TVD 8173 Completion Date 7/27/2017 ED C 28425 Digital Data Log C 28425 Log Header Scans Log C 28446 Log Header Scans ED C 28446 Digital Data ED C 28446 Digital Data ED C 28446 Digital Data ED C 28446 Digital Data ED C 28446 Digital Data ED C 28693 Digital Data ED C 28693 Digital Data ED C 28693 Digital Data ED C 28693 Digital Data ED C 28693 Digital Data ED C 28693 Digital Data Log C 28693 Log Header Scans ED C 28693 Digital Data ED C 28693 Digital Data ED C 28693 Digital Data AOGCC Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 Completion Status 1 -GAS Current Status 1 -GAS UIC No 7/19/2017 Electronic File: Hilcorp_Kalotsa_3_XPT_22-Jun- 2017_FINAL.pdf 0 0 2170280 KALOTSA 3 LOG HEADERS 0 0 2170280 KALOTSA 3 LOG HEADERS -38 9167 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa3_SCMT_CBL_8July2017_Main.1 - as 8474 9161 7/19/2017 Electronic Data Set, Filename: Hiloorp_Kalotsa3_SCMT_C B L_8J uly20l7_Repea Llas 7/19/2017 Electronic File: Hi Icorp_Kalotsa3_SCMT_C B L_8J uly2017_ConC u_MainAlis 7/19/2017 Electronic File: Hilcorp_Kalotsa3_ SCMT_CBL_8Ju1y2017_ConC u_RepeaLdlis 7/19/2017 Electronic File: p Hilcorp_Kalotsa3_SCMT_CBL_08JUL17_FINAL. t Pdf n10/17/2017 1-10/17/2017 Electronic File: KALOTSA-3_PERF_27JUL17,pdf Electronic File: KALOTSA- 3_PERF_27JUL17_LAS.zip ' 10/17/2017 Electronic File: KALOTSA- 3_PERF_27JU L 17_img.tif 10/17/2017 Electronic File: KALOTSA-3_PRESS- . TEMP_23AUG17.pdf 10/17/2017 Electronic File: KALOTSA-3_PRESS- TEMP_23AUG17_LAS.zip - 10/17/2017 Electronic File: KALOTSA-3_PRESS- TEMP_23AUG17_img.tif 0 0 2170280 KALOTSA 3 LOG HEADERS 9126 8772 10/17/2017 Electronic Data Set, Filename: CORRE LATION_G U N 1.las 9114 8774 10/17/2017 Electronic Data Set, Filename: _ CORRELATION GUN2.Ias 10 9126 10/17/2017 Electronic Data Set, Filename: DOWN LOG.Ias Page 15 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50-133-20661-00-00 MD 9265 TVD 8173 Completion Date 7/27/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28693 Digital Data 9155 8898 10/17/2017 Electronic Data Set, Filename: FLUID LEVEL.Ias ED C 28693 Digital Data 9129 8943 10/17/2017 Electronic Data Set, Filename: PERFORATION_ GUN 1.1as ED C 28693 Digital Data 9128 8954 10/17/2017 Electronic Data Set, Filename: PERFORATION_ GUN 2.1as ED C 28693 Digital Data 0 622 10/17/2017 Electronic Data Set, Filename: STATION IN THE HANGER.las ' ED C 28693 Digital Data 0 1926 10/17/2017 Electronic Data Set, Filename: STATION ON - BOTTOM.Ias ED C 28693 Digital Data 9126 -5 10/17/2017 Electronic Data Set, Filename: UP LOG.Ias ED C 28791 Digital Data 8986 8704 11/13/2017 Electronic Data Set, Filename: CORRELATION• PASS PERF ONE.Ias ED C 28791 Digital Data 9128 8860 11/13/2017 Electronic Data Set, Filename: CORRELATION.Ias ED C 28791 Digital Data 9020 8681 11/13/2017 Electronic Data Set, Filename: FLUID LEVEL LOG.Ias ED C 28791 Digital Data 8992 8896 11/13/2017 Electronic Data Set, Filename: PERFORATION PASS.las ED C 28791 Digital Data 9116 8898 11/13/2017 Electronic Data Set, Filename: PLUG SET.Ias ED C 28791 Digital Data 1/13/2017 Electronic File: KALOTSA 3_PERF_26SEPT17.pdf ED C 28791 Digital Data 11/13/2017 Electronic File: KALOTSA 3_PERF_26SEPT17_LAS.zip ED C 28791 Digital Data 11/13/2017 Electronic File: KALOTSA 3_PERF_26SEPT17_img.tif ED C 28791 Digital Data 11/13/2017 Electronic File: KALOTSA ? 3_PLUG_10SEPT17.pdf ED C 28791 Digital Data 11/13/2017 Electronic File: KALOTSA 3_PLUG_10SEPT17_LAS.zip ED C 28791 Digital Data 11/13/2017 Electronic File: KALOTSA 3_PLUG_10SEPT17_img.tif Log C 28791 Log Header Scans 0 0 2170280 KALOTSA 3 LOG HEADERS Well Cores/Samples Information: —- - — --- -- - Interval SampleSet Name Start Stop Sent Received Number Comments AOGCC Page 16 of 17 Friday, December 15, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2017 Permit to Drill 2170280 Well Name/No. KALOTSA 3 Operator HILCORP ALASKA LLC API No. 50.133-20661-00-00 MD 9265 TVD 5173 -- Completion Date 7/27/2017 Completion Status 1 -GAS Current Status -�/ 1 -GAS UIC No Cuttings 1412 9264 - - - --7/19/2017 1611 - - - - - INFORMATION RECEIVED'� - - - - - Completion Report V Directional / Inclination Data /Y 1 Mud Logs, Image Files, Digital Dat NA Core Chips Y Production Test Information Y /©A Mechanical Integrity Test InformationlYY 111 Composite Logs, Image, Data Files © Core Photographs Y Geologic Markersfrops YO Daily Operations SummaryYD Cuttings Samples �Y NA Laboratory Analyses Y / A COMPLIANCE HISTORY - - - - - - - - - - Completion Date: 7/27/2017 Release Date: 3/8/2017 Description Date Comments Comments: - -- - -- -- - - - -- - - _ -- Compliance Date: AOGCC Page 17 of 17 - Friday, December 15, 2017 Please acknowledge rript by suing and returning one copy of this transmittal or FAX to 907 777.8337 Date: Q 2-ot�- Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 :%h,A._ LLC Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 12/15/17 To: AOGCC Meredith Guhl 333 W. 71h Ave. Ste#100 Anchorage, AK 99501 CD1 Kalotsa 3 21q -b26 . Hiloorp_Kalotsa3_PN% 09JUL17 711BJ20178:09 AM File folder Tze)CiZ3 CD 2 Kalotsa 4 . PERF_31AUG17 12/14/20172:53 PM File folder PRESSTEMP_23AUG17 12/14JZ0172:53PM File folder "�✓ (..� . PERF_25AUG17T2"g 1 12/14f2017 2:38 PM File folder Please induce current contact information if different from above. m C") m 0 /0 G) c r � � m Please acknowledge rript by suing and returning one copy of this transmittal or FAX to 907 777.8337 Date: Q 2-ot�- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS V Cu NOV 13 2011 AOGCC 1. Operations Abandon LJ Plug Perforations Fracture Stimulate Li Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill Elerforate New Pool ❑ Repair Well El Re-enterSusp Well El Other: ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑✓ Stratigraphic❑ Exploratory 111 Service ❑ 217-028 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20661-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: C061505 SHL / ADL359242 / ADL384372 TPH/BHL Kalotsa 3 9. Logs (List lags and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik Field - Beluga/Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,265 feet Plugs measured 9,007 feet true vertical 8,173 feet Junk measured N/A feet Effective Depth measured 9,007 feet Packer measured 1,280 feet true vertical 7,916 feet true vertical 1,203 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,316' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A; N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker Swell Pkr 1,280' MD 1,203' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-McfWater-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 52 0 0 766 Subsequent to operation: 0 0 0 0 135 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.263) 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 El Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 317-440 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerridhilcom com Authorized Signature: &ZI06LDate: )O 1 I'Zfh7'Contact Phone: 777-8420 Form 10-404 Revised 4/2017,d ('/V�7RBQnS r V Kd'� 1 4 2017 Submit Original Only �!r Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 3-PerfT-145 E-Line 50-133-20661-00 217-028 9/26/17 9/26/17 Daily Operations: 09/26/2017-Tuesday Mobe to location. PTW and JSA. Rig up Lubricator, PT to 250 psi low and 4500 psi high. TP - 2400 psi. RIH w/GPT tool, tie into OHL and tag at 9008'. Found fluid level at 9004' with 2400 psi on well. POOH. RIH w/2-7/8N20' Razor HC, 6spf, 60 deg phase perf gun, tie into OHL and tag at 9008'. Run correlation log and send to town. Bleed well down to 2234 psi. Get ok to perforate from 8975' to 8995'. Spotted gun and fired with 2234 psi on tubing. After 5 min pressure was 2235.2 psi, 10 min was 2234.8 psi and 15 min - 2234.1 psi. POOH. All guns fired and gun was wet. Rig down lubricator and turn well over to field. —� 16„ Ninilchik Unit KaloSCHEMATIC PTD: a 2177-- 11 PTD: 028 Hi1ew� AWk+, LLC API: 50-133-20661-00 RKB to GL= 19.1' 6-3/4" Type Wt -. Hole ID Top Btm RA @ 3,987' r S4 X-56 RA @ 5,438' w Surf 120' RA @ 6,474' Surf Csg 29.7 L-80 BTC 6.875" Surf 1,418' RA @ 7,470' •a 12.6 _ TXP 3.958" Surf 9,252' is ' 1146 roc @9,007 09/10/17 -- T147 4-1/2" PBTD = 9,007'/ PBTVD = 7,916' TD = 9,265'/ TVD = 8,173' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor—Driven to Set Depth S4 X-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 9,012' 7,904' 3.958" CIBP w/ 5' of cement 9/10/17 OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Btm (MD) Class G tail. 100% returns throughout, 30 bbls to surface. 4-112- 6-3/4" hole. 240 BBL (675 5x)12.5 Type 1 -II cement, followed with 32 BBL (1605x) of I Date Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) I Btm (TVD) I Ft I Date I Status 146 8,975' 8,995' 7,884' 7,904' 20 09/26/17 Open T147 9,022' 9,033' 7,931' 7,942' 11 07/27/17 Isolated Updated by DMA 10-25-17 Seth Nolan GeoTech Ifilenrp :lln.km. Id.(: REC NOV 11'3(/2`+0117+. DATE 11/10/2017 AOGC ,i Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA Prints and Digital data Prints: PERFORATION RECORD PLUG SETTING RECORD CD1: . PERF.2 EPT17 10/19/20173:13PM File folder . PLUG_10SEPTI7 10/19120173:12PM File folder Please include current contact information if different from above. 21 7028 28 79 1 DATA LOGGED Lk 44/2011 0 K BENDER Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: v Seth Nolan GeoTech Hilrorp alnnka,l.LC RECEIVE V OCT 17 2017 AOGCC DATE 10/02/2017 Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA Prints and Digital data Prints: PERFORATION RECORD STATIC BOTTOM HOLE PRESSURE SURVEY CD1: . PERF_273UL17 PRESS -TEMP 23AUG17 9/21/2017 10:56 AM File folder 9/21/2017 11:01 AM File folder Please include current contact information if different from above. 21 7028 28695 DAIA L03GED 10 1742ot1 M K. BENDER Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED OCT 0 2 2017 WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil ❑ Gas 2 - SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAc 25.105 20AAC 25A10 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: _ 1 1b. Well Class: Development ❑� Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name:Date Hilcor Alaska, LLC P Com Susp., or . L 7k7 Aband.: ,.,W4 17 14 Permit to Drill Number / Sundry: 1 T 317 - 31 217-028 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: q„ ++-' LL June A, 2017 1 It—API Number: 317-y 50-133-20661-00-00 4a. Location of Well (Governmental Section): Surface: 2262' FSL, 458' FWL, Sec 7, T1S, R13W, SM, AK Top of Productive Interval: 748' FSL, 716' FEL, Sec 1, TIS, R14W, SM, AK Total Depth: 769' FSL, 723' FEL, Sec 1, T1 S, R14W, SM, AK 8. Date TD Reached: June 20, 2017 16. Well Name and Number: Kalotsa 3 9. Ref Elevations: KB: 144.5' • GL:126.5' BF:125.5' 17. Field / Pool(s): Ninilchik Field Beluga / Tyonek Gas Pool 10. Plug Back Depth MD/rVD: 9,007 MD /7,X7' TVD-Wl 1,8. Property Designation: (SHL) C061505'/ (TPH/BHL) ADL384372. 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 209857• y- 223353517 Zone- 4 TPI: x- 208775 y- 2237244 Zone- 4 Total Depth: x- 208769 y- 2237264 Zone- 4 11. Total Depth MD/TVD' , , . 9,265' MD / TVD 19. DNR Approval Number: . y.�'/7 LOCI 16-004 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MDfFVD: N/A 5. Directional or Inclination Survey: Yes j (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, 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 2"15" ROP-DGR-EWR- CTN-ALD MD, 2"/5" DGR-EWR-CTN- ALD TVD ECS -GR, HNGS-GR, PNX-GR, PNX-PBMS, CBL-VDL-GR-CCL ✓ 5" FORMATION LOG MD+TVD, 2" FORMATION LOG MD/TVD, 2" LWD COMBO LOG MD/TVD 2" GAS RATIO LOG MD/TVD, 2" DRILLING DYNAMICS MDITVD, FINAL WELL REPORT 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM PULLED 16" 84# X-56 Surface 120' Surface 120' Driven 7-5/8" 29.7# L-80 Surface 1,420' Surface 1,336' 9-7/8" L - 200 sx / T - 155 sx 30 bbls 4-1/2" 12.6# L-80 Surface 9,254' Surface 7,990' 6-3/4" L - 675 sx / T - 160 sx 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9,022' - 9,033' MD / 7,762'- 7,773' TVD on 7/27/17 (PLUGGED BACK)" 8,975' - 8,995' MD / 7,716' - 7,735' TVD on 9/26!17 2-7/8", 6 SPF COMPLETION DATE '1Y-71, �.-t / VERIFIED '/fit- L+.- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� , Per 20 AAC 25.283 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: TBD Method of Operation (Flowing, gas lift, etc.): TBD Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate . 0. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Ip A /z -z-17 Form 10-407 Revised 5/2017 �-,/ CONTINUED ON PAGE 2 RBDMS L' r:,. _ 3 2017 Submit ORIGINIAnl ,Z i 1tl/` y_ / J 28. CORE DATA Conventional Core(s): Yes ❑ No Q ' Sidewall Cores: Yes Q No ❑ If Yes, list formations and intervals cored (MDTFVD, 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. Sidewall core data will be submitted separately when fully processed 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top « Permafrost - Base ,�JW4 R7Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval ��U information, including reports, per 20 AAC 25.071. T3 4465 3831 T6 4777 4089 T65 7539 6460 T83 7848 6764 T90 8006 6921 T140 8562 7473 Formation at total depth: T150 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports 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. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdin er a hilCor .Corti Authorized ,Pq�� M Contact Phone: 777-8389 Signature: Date: INSTRUCTIONS General: 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. Item 1 a: 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. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only n I .c RKBtoGL=18' Current Schematic Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 CASING DETAIL Size Type y Grade Conn. ID 6-3/4„ Btm 16" Hole 84 ^ 7 rr RA @ 3,987' s 15.01" - RA@5,438' * 7-5/8" Surf Csg 29.7 L-80 rM1+ .�+': RA @ 6,474' Surf 1,420' Current Schematic Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00-00 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 BTC 6.875" Surf 1,420' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,254' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 9,012' ( 3.958" CIBP w/5'cement 09/10/17 OPEN HOLE/ CEMENT DETAIL 7 5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx)15.4 ppg Btm (MD) Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2" 6-3/4" hole. 240 BBL (675 sx) 12.5 Type 1-11 cement, followed with 32 BBL (160sx) of Date Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm FT Date Status ( T146 8,975' 8,995' 7,716' 1 7,735' 20 9/26/17 1 Ope T147 9,022' 9,033' 1 7,762' 1 7,773' 11 07/27/17 [,.fated RA @ 7,470' dAe _ TOC @ 9,007' 09/10/17 1• -.. T147, PBTD = 9,007' / PBTVD = 7,747' TD = 9,265'/ TVD = 8,724' Updated by CJD 10-2-17 "3) QA' U n Well Name: NINU Kalotsa 3 Field: Ninilchik County/State: ,Alaska (LAT/LONG): evasion (RKB): 18 API#: 50-133-20661-00 Spud Date: 6/8/2017 Job Name: 1710632D Kalotsa 3 Drilling Contractor AFE #: AFE $: Hilcorp Energy Company Composite Report Ops summa 6!512017 , Lay down derrick. Scope down dog house. Un hook all hydraulic lines. Disconnect and secure all power lines Secure Gens for move Pick up handiberm, move third party shacks to side yard.;Secure cables, hoses, clamps on pits for move. Prepare skate for crane pick. Move all extra equipment to side yard with loaders. 6/6/2017 Prep brake linkage for inspection. Move cartvalk and doghouse. Lay down felt, cleaned liner edge and seam on additional liner. Rig up trucks to sub base and skid sub base forward.;Spot generator modules, dog house, mud pits and mud pumps.;Spot boiler house. Lay out liner for catwalk and seam. Set catwalk. Raise dog house. R/U and half mast derrick. Hook up electrical, mud and water lines. Set centrifuge on stand. Set gas buster.;Spot Gen 3, Rig up all remaining power lines, ground lines, drive ground rods (certified by production), power up generators, install newly inspected brake linkage, install lower Kelly hose, service;loop, install tum buckles on torque tube, function adjust brakes, move 6 matting boards from backside of dg for drive way.;Cul 118' of drilline, spool drill line on, slip line, prepare derrick for scoping. Spot 3rd party work shacks, prepare yard for receiving surface casing, lay out dunnage. Fold roof gaps on mud tanks.;Unspool winch lines on rig floor, install winch line rollers, air up mud pump suction line air bags, rig up Pasch lines, rig up iron roughneck, scope derrick to full height. Pick up top drive. 6/72017 Continue rigging up top drive. Install torque hushing and service loop. Replace double ball valve. Rig up centrifuge. Install skate on catwalk. Rig up rig tongs. Replace drill line spool.;Change out weight indicator on derrick. Install Kelly hose. Install saver sub. Check end play and back lash on TDS. Air out mud pumps and function test. Function test iron rough neck. Install 4";valves on conductor and function test from surface.;Finish installing conductor, install flow line/chains/binders/cellar grating/cellar grating lock tabs. Function test MP#1 & 4112. Lube liners. Set alarms. Rig up mud saver, grabber interlocks, set crown;O-matic. Change out off take valve on bottom of pit #1. build spud mud. 390 bbis. Function test cat walk ESD, all motor ESD's. Re -set handiberm by catwalk. Total Gas setting up gas alarms systems.;Find failed computer board. New one coming in the morning. Prepare to pick up drill pipe. Rig accepted 23:59 hrs.;Pick up and stand back 20 joints 4.5" DP. Dummy run surface hanger. Set wear bushing. Pick up and rack back 50 more joints DP, 9 HWDP and jars. Tag bottom @ 123.8'.;Bring BHA components to rig floor. SIMOPS: Test run centrifuge. 6/8/2017 Fill lines and conductor. Close IBOP and PT surface lines. Observe flange on riser leaking, tighten flange. Total safety working on gas detection system - appears to have a short.;Service rig, check drive line bolts, grease drawworks, iron roughneck while continuing to troubleshool1tesl gas alarms.;Pick up motor and make up used 9-7/8" Smith bit (2-6) to 123': Drill9-718" hole from 123'to 250'; 350 ppm/500 psi, 40 rpms/5000 ft-Ibs.;Circulate hole clean at 420 gpm/600 gpm. Attempt to pump first stand out of hole, light. Back ream out of hole 60 rpms erratic torque 5000-13000 ft -lbs to 128'. POOH. UD bit (2-6).;Make up 9- 718" MM65 bit (1-1 grade) to 7" SperryDrill Motor with 1.5" bend. Pick up MWD tools. Measure RFO (265.9°). Upload to EWR-P4 collar (res). Continue to RIH washing last stand to botlom.;Continue drilling 9-7/8" hole from 250' to 389' sliding as needed to WP maintain and build 4°/100'. WOB 3-5K,450 gpm/1100 psi, 50 rpms/5000 ft-Ibs.;Directional drill 9.875" surface hole from 389 to 1011' MD. 500 GPM, 50 RPM, 1480 PP 1600 PP off, on, TQ 4800 ft/Ibs og, 6200 ft/lbs on. Slide 20 to 32 feet off the top of each stand to achieve 4°;build rates as per WP05. P/U 39k, S/O 37k, Rot 38k. Back ream each stand. Drilled 80% clay, and 20 % sand. Max gas 84 units. MW 9 ppg, ECD 9.65 ppg.;Directional drill 9.875" surface hole from 1011 to 1099' MD. 500 GPM, 50 RPM, 1500 PP off, 1650 PP on, TO 4800 flllbs off, 6200 Mbs on.;Circulate on Mud Pump #1. replace leaking pop off valve on #2. 250GPM, 700 PP.;Directional drill 9.875" surface hole from 1099 to 1423' MD. 550 GPM, 80 RPM, 1700 PP off, 1950 PP on, TO 65001tgbs off, 8500 ft Iles on. UP 42k, DN 36k, Rot 39k. MW 9.2 ppg ECD 9.76.;Survey, SPR's, Pump sweep. Circulate and condition with 550 GPM, 80 RPM. 20 % increase in cuttings seen on shakers with sweep. CBU 2 more times. shakers cleaned up.;Pump out two stands. 1423 to 1319'. Monitor well. Static. POOH on elevators from 1319' to 600'. Good hole fill. No drag.;Wellbore position: 9' from plan. 8' high. 4' left.;72 bbls solids to G&1, 72 bbis cum. 108 bbis class II fluid to G&I, 108 bbls cum 0 bbis cement to G&I, 0 bible cum 0 bible mud loss down hole, 0 bbis cum 6/9/2017 Continue to POOH from 600', tight at 390' and 338'. Able to orient through 395'. At 338' RIH to 390' and back ream to268'to clean up ledges slides; 30 rpms/500-6500 ft -lbs, 340 gpms/670 psi.;at 268' continue to POOH on elevators with no issues. UD BHA and flex collars. Download, L/D MWD, bit and motor. Bit grade 1-iJD-G-X-I-NO-TD.;Clean and clear rig floor. Pull wear bushing, dummy run hanger. Rig up casing bales and Weatherford casing equipment. Bring centralizers to rig floor.;Make up shoe track, Bakerlok to pin end 4th joint. Check floats (good). RIH with 7-5/8" casing. Set down at 355' and 465' and work through fairly easy, observe pipe turn as working through, no;overpull. Set down again at 495' work down to 505' (no overpull, pipe turning) and unable to work past. Swedge up and break circulation staging up to 314 gpm/100 psi while working pipe. Signifcant;clay observed over shakers. Work through tight spot. Continue RIH to 1387'. Circulate at 790' and 1150' as drag increases and pipe becomes sticky on downstroke (no overpull). Average MU T0= 7200.;3x annular volume 300 gpm significant clay observed at shakers cleaning up after 3 x annular volume. Make up hanger and land casing at 1412.65'. Max gas 36 units. No mud losses, full returns.;Make up circ swedge/ 15' h hose. Circulate and reciprocate while rigging up cementers on rig floor. 4x's. 255 GPM, 225 PP, 29% flow. Up 50k, Dn 38k. Rig up cement manifold, load orange bottom launcher hardline, esU plug.;MU single plug and Hal loaded lines with 2 bbis water and checked for leaks. Hal pressure tested lines at 1300 low 3300 high, good tests. Hal. pumped 31.3 bbls 10 ppg Clean Spacer;lll at 3 bpm and shut down. Hal. dropped bottom plug, (Kicked out with one BBL Spacer, then loaded solid plug). and pumped 86 bbis 200 sx 12 opa Class A lead cement atbprn ;follo-cl by 36 bbis (150 sx) 15.4 ppg Class G tail cement at 4 bpm. Hal dropped top plug, then displaced with 60 bbls 9.2 ppg Spud Mud at 5 bpm, ,4 psi. Slowed to 3 bpm with 10 bbl to go.;Bumped the plug, and held 1100 psi (FCP of 550 psi) for 5 minutes, bled off and floats held. Bled back .75 bbl to lllJJl truck. Had 31 bbls Spacer return to surface and 30 bbls of good 12 ppg lead cement to;surface. Mix water temp at 78 deg. Pumped 112% excess on lead and 50% tail. Reciprocate the string throughout thejob. Had no losses. With Red Dye/ Spacer to surface,;diverted remaining returns to cellar box through the 4" outlet on conductor. Up wt 50K, dwn wt 38K at time of landing hanger.CIP at 22:45 hrs, 6/9/2017 RD and released Hailiburion.;Wash up cement lines and equipment. Clean out cellar. Blow back all lines, Begin to rig down Halliburton cementem.;Lay down landing joint. Set pack off with Well head hand. Finish rigging down and cleaning up Halliburton cementers. Suck out cellar, flush hanger. Lay down landing joint.;Rig down casing bails, elevators, rig up drilling bails and elevators.;Rig down chains, binders on riser, rig down flowline, remove cellar grating, bracing, remove surface hole riser. Set Cactus well head spool with e Head hand. Nippleu . Spot crane. Raise V-door.;Spot BOP cradle with Peak tail roll truck. Set BOPE stack with Peak crane. 1492 Manitowoc. SIMOPS: Wash mud pits, haul off old mud. Test pack off void, 500 psi 5 min low, Sk psi 15 min high.;72 bids solids to G&I, 144 bbis cum. 332 bbis class 11 fluid to GO 440 bbis cum 46 bbis cement to G&I, 46 bbis cum 0 bbis mud loss down hole, 0 bbis cum 6/10/2017 Move flaw line, install trolley beam. Stab BOP onto DSA. NIU BOP. Hook up kill/choke lines/valves. Retighten DSA bols.;Drop trolley beam, install catch -can. Pressure up accumulator lines and function test BOP's. Continue building 6% KCL/PHPA mud.;Level sub base. Install bell nipple. Set wear bushing. Load drill pipe on pipe rack. Open ram doors in preparation foryearly inspection. Recalibrate rigsmart. Continue building 6% KCL/PHPA mud.;Perform required yearly BOPE non destructive inspection with Rig Mechanic and Tuboscope Inspector. Caliper all ram bore inside diameters, ram body outside diametem.;Install all rams, close doors, tighten door bolts, pressure up accumulator, low pressure function all rams. Hammer up single gate and spacer spool flanges. Pick up and install mouse hole.;Tally 30 joints of 4.5" DP. Single in the hole, and trip out standing back 15 stands. Each joint drifted. 50 stands in derrick.;Tally 30 joints of 4.5" DP. Single in the hole, and trip out standing back 15 stands. Each joint drifted. 65 stands in derrick.;Tally 30 joints of 4.5" DP. Single in the hole, and trip out standing back 15 stands. Each joint drifted. 80 stands in demick.;Tally 30 joints of 4.5" DP. Single in the hole, and trip out standing back 15 stands. Each joint drifted. 95 stands in derrick. SIMOPS: Clean suction/discharge screens. Ck pulsation dampners. 650 each;Tally 30joints of 4.5" DP. Single in the hole. Crew change.;4 bbis solids to G&l, 148 bbis cum. 266 bbis class II fluid to G&I, 706 bbis cum 0 bbls cement to G&1, 46 bbis cum 0 bbis mud loss down hole, 0 bbis cum 6/11/2017 Continue picking up drill pipe, 30 joints and rack back.;Clean rig floor. Pull wear bushing. Set test plug, fill stack.:Test BOPS 250/3500 psi. !annular 2500snm 4-1/2" test joint. AOGCC right to witness waived by Jim Regg. Total safety tested all gas alarms. RP on choke HCR, and annular. Function and bleed air;retest good. Accumulator drawdown: starting pressure 3050 psi, final pressure 1450 psi. 200 recharge in 22 sec, full recharge in 99 sec. 4N2 bottle with 2712 psi avemge.;Puil test plug. Install wear bushing.;Prejob safety meeting. Discuss pressure and valve alignment. Pressure up to 3600 psi o Ch -rt 30 mins. Pumped 39.3 gals, bled back 39 gals. Good test. Held 99.5% test pressure. blow down Iines;Prejob. Make up BHA#3 with DD nds. PDand MWD haC Varel bit, Mud motor @ 1.5°, MWD Tripple Combo.;Up load MWD tools. Clean out pit 4.;Make up BHA#3 from 109' to 480' MD. Taking all returns in and out of pit 03. SIMOPS: Clean pit 114, transfer new 9116% PHPA KCL into pit #4. Strap, tally 24 joints of DP.;Single in the hole with 24 joints of CDS40 4.5" DP from 480' to 1227'. TIH with two stands to float collar.;Drit float collar @ 1329'. (Tagged 5' low), Clean out shoe track to shoe @ 1412'. (Tagged 5' low), Drill shoe, "i,, and clean out rat hole to 1423'. 250 GPM, 50 RPM, Drill 20 feet of new hole to 1443' MD.:Displace well from spud mud to 6% PHPA KCL mud. 280 GPM, 30 RPM, 1295 PP, 4600 TO. Shut down clean pit 3. Shaker beds. Troughs, Gel up gates. Transfer mud into pit #3.;Formation integrity test. Circulate surface to surface. Rack back one stand. Rig up to conduct FIT. Make up head pin, tie in test pump to mezzanine kill line valve. Pump 4.3 gallons. 360 psi.;Good test. 14.26, rounded down to 14.2 ppg EMW FIT. Bleed back 3.3 gallons.;Directional drill from 1443' to 1510'. 250 GPM, 50 RPM, 1300 PP.;3 b61s solids to G&I, 151 bbis cum. 57 bbls class II fluid to G&I, 763 bbis cum 0 bible cement to G&I, 46 bbls cum 0 bbis mud loss down hale, 0 bbis cum 6/12/2017 Continue drilling 6-314" hole from 1510'to 2468', maintenance slides as needed. MAD pass all slides. sliding parameters: ROP 175 fph, WOB 3K, 275 gpm/1478 psi with 227 differential.;Rotating parameters: ROP 150 fph, WOB 24K, 270 gpm/1550 psi, 80 rpms/7000 ft -lbs. ECD's 10.5 ppg EWM with 9.05 ppg mud. Pump high viscosity sweeps at 1785'(50%), and 2096'(25%) both sweeps on time.;Short trip depth- Survey, pump sweep surface to surface. 30% increase in cuttings. Up 55k, Dn 44, Rot 48k. 270 GPM, 70 RPM, PP 1550. MW 9.05 ppg, ECD 10.5 ppg.;Pump out two stands, one pump in idle. POOH on elevators into casing. Trip from 2466 to 1409. Hole fill. 6.8 Calc. Actual 9 bbls. 2.2 bbis Iong.;Rig service. Monitor well on trip tank. .5 bbl/hr loss rate. Grease, inspect blocks, top drive, drive shafts, check all pins and keepers.;TIH to 2408, Wash last stand down. Make connection. No fill on bottom.;Drill from 2468! to 2718' MD. 270 GPM, 85 RPM, 1350 PP off, 1550 PP on, 10.57 PPG ecd, 9.15 PPG. mw, Max gas 90 units. 6500 TO off, 7500 TO on, 8k WOB. 50% increase in cuttings from sweep after ST.;Ddll from 2718' to 3225' MD. 270 GPM, 85 RPM, 1250 PP off, 1550 PP on, 10.65 PPG ace, 9.15 PPG mw, Max 181 units. gas 6500 TO off, 7500 TO on, 8k WOB. 50% increase in cuttings from sweep @ 2845.;P/U 64k, S/O 48k, Rot 56k,;95 bbis solids to G&I, 246 bbis cum. 445 bbis class II fluid to G&I, 1208 bbis cum 0 bbis cement to G&L 46 bbis cum 10 bbis mud loss down hole, 10 bbis cum;Wellbore position: 3'to plan, 2' low, 2 feet left. GGLS�nc .,rcSV 6/13/2017 Continue drilling 6-3/4" hole from 3225'to 3465' as per WP0T Rotating parameters: ROP 145fph, 250 gpm/1590 psi, 80 rpms/8000 it - Ibs ECD 10.85 ppg with 9.15 ppg mud. No slides.;Pump high viscosity sweep (20%, 12 bbis early) and circulate hole clean 2 x hole volume; 250 gpm/1390 psi 50 rpms 6300 ft. lbs. Flow check, static.;Wiper trip. POOH to from 3465' (PUW 80K, SOW 54K) to 2406'. Tight spot at 2483' with 30K over, wipe clean.;Service rig; grease crown, drawworks, blocks. Check driveline botts.;RIH from 2406'to 3465; tight at 3373'(25K) work through. Wash last stand to bottom.;Continue drilling from 3466to 3480'. Pump sweep at 3465', on time with 50% increase in cuttings. Slide as needed to maintain WP0T MAD pass all slides. Sliding parameters: 185fph, WOB 3K.;270 gpnJ1700 psi with 290 differential. Rotating parameters: ROP 150 fph, 280gpm/1861 psi, 80 rpms/8200 ft-Ibs. ECUs 11.2 ppg with 9.1 ppg mud. Pump sweep at 3775' (50% on time).;Cont. drill ahead 6 3/4" production hole from 3465' to 4458', 276 gpm, 1700 psi, 5 -10 k wob, 60 - 80 rpm, 8 - 9.5 k h/Ibs trq, PU wt 86 k, SO w158 k, ROT wt 70 k.;ECD 11.25 ppg with 9.25 ppg mud. Pumping sweeps every 300'to aid in hole cleaning, average 20 - 30% increase in cutlings.;Pump sweep & circ hole clean for a total of 5 B/U. 30% increase in cuttings with sweep.;POOH wiper trip from 4458' to 1410' No issues.;Distance to plan: 3.71' (3.38' High / 1.51' Left).;121 bbl, solids to G&I, 367 bbls cum. 419 bbls class II fluid to G&I, 1627 bbls cum 0 bbis cement to G&1, 46 bbis cum 37 bbls mud loss down hole, 47 bbis cum 6/14/2017 Service rig.;RIH from 1410'to 4458'; tight at 31 15'with 20K down, wipe clean. Consistent 0 -10K dreg from 2800' to 3800'. Wash last stand to bottom.;Circulate annular volume reciprocating pipe; 230 gpm/1555psi, 50 rpms/7000 ft -lbs. Wiper gas 541 u.;Continue drilling 6-3/4" hole from 4458' to 5052', sliding as needed to maintain ill MAD pass all slides. Pump sweeps at 4458'(30%), 4772'(30%). Sliding parameters: ROP 180rph,;WOB 5-7K, 278 gpm/2116 psi with 390 psi diff. Rotating ROP 120-150 fph, WOB 4-81K, 273 gpm/2130 psi, 60-80 rpms/ 8300-10Kft-Ibs, ECDS' 11.51 ppg with 9.3 ppg mud.;Cont. drill ahead 6 3/4" production hole from 5052' to 5452', 287 gpm, 1950 psi, 5 -10 k wob, 60 - 80 rpm, 8 - 9.5 k ft/lbs trq, PU wt 110 k, SO wt 67 k, ROT w182 k.;ECD 11.20 ppg with 9.35 ppg mud. Pumping sweeps every 300'to aid in hole cleaning, average 20 - 30% increase in cuttings.;Pump sweep & circ hole clean for a total of 3 BA). 75% increase in cuttings with sweep.;POOH wiper trip from 5452' to 439T (no issues). F/C. RIH from 4397' to 5452' (30k tight spot @ 5110', work thru once & clear).;Circ B/U with 284 gpm, 2150 psi, 50 rpm, 8.5 - 9.5 k trq. Attempt to un -plug MWD stator channel.;Cont. drill ahead 6 3/4" production hole from 5452' to 5610', 285 gpm, 2000 psi, 5 -10 k wob, 60 - 80 rpm, 9 -10.5 k ft/Ibs trq, PU wl 112 k, SO wl 69 k, ROT wt 84 k.;ECD 11.20 ppg with 9.35 ppg mud. Pumping sweeps every 300'to aid in hole cleaning, average 20 - 30% increase in cuffings.;Distance to plan: 9.74' (9.74' Low/ .35' LefQ.;79 bbis solids to G&I, 446 bbis cum. 361 bbis class II fluid to G&I, 1988 bbis cum 0 bbls cement to G&I, 46 bbis cum 57 bbis mud loss down hole, 104 bbis cu 6/15/2017 Continue drilling 6-3/4" hole from 5610' to 6450' as per WP07, sliding as needed to maintain III MAD pass all slides. Pump high vis sweep at 5893' (700/6), low visNveiglit sweep at 6200' (75%).;Sliding parameters: ROP 125-160 fph, WOB 4-6K, 284 gpm/2550psi with 380psi diff. Rotating parameters: ROP 150fph, WOB 4-8K, 284 gpms/2500 psi, 80 rpms/11400ft-Ibs ECUs 11.4-11.5 ppg with 9.35ppg mud.;Pump tandem sweep (low vis followed by high vis weighted). Circ hole clean for wiper trip 4 B/U. 300 gpm, 2350 psi, 60 rpm, 9.5 - 10 k Mbs trq.;100% increase in cuttings with sweep, fine sands with a mix of coal. Pumped 3rd sweep with 75% increase in cuttings.;POOH wiper trip from 6450'to 5393'. Hole fill calc 6.4 bbis / act 7.1 bbis (30 k tight spots 5612' & 5540').;Service rig.;RIH from 5393'to 6450' W&R last stand to bottom. No Fill. Disp calc 6.4 bbls / act 6.3 bbls.;Pump sweep & circ B/U. No increase in cuttings with sweep. Max gas 3113 units.;Cont, drill ahead 6 3/4" production hole from 6450' to 6798', 295 gpm, 2300 psi, 5 -10 k wob, 60 - 80 rpm, 11 - 12.5 k ft/Ibs trq, PU will 137 k, SO wt 75 k, ROT wt 94 k.;ECD 11.0 ppg with 9.3 ppg mud. Pumping sweeps every 300'to aid in hole cleaning, average 50 - 75% increase in cuftings.;Distance to plan: 4.5' (4.46' Low 1.6' Left).;76 bbis solids to G&I, 522 bbis cum. 284 bbls class II fluid to G&I, 2272 bbis cum 0 bbls cement to G&I, 46 bbls cum 20 bulls mud loss down hole, 124 bbls cum 6/16/2017 Continue drilling 6-3/4" hole from 6798'to 7014'. Sliding as needed to drop 2°/100 as per WP0T Sliding parameters: ROP 50-180 fph, 293 gpm/2714psi with 327 diff.;Rotating parameters:150 fph, 294 gpm/2750 psi, 80 rpms/11700 ft-Ibs, WOB 5-71K. ECUs 11.05 ppg with 9.3 ppg mud.;At 7014', top of the stand shale shaker shutdown. Circulate hole on one shaker 148 gpm while troubleshooting. Stand back 2 stands and continue circulating staging up to 250 gpm as shaker allows.;contacts in shaker starter observed to be bad, not supplying 120V to motor causing breaker to burnout. Replace contacts and bmaker.;RIH and continue drilling from 7014' to 7448' sliding as needed, MAD pass all slides. Sliding ROP 50-100fph, 290gpm/2561 psi with 210 diff. Rotating 110-150 fph, 290 gpm/2700 psi, 80 rpms/12600ft-lbs.;ECD's 11.2 with 9.45ppg mw. Pump sweep a1 7090'(40% excess). Observe connection gas at 7202'(53U), 7263' (152U); increase mud weight from 9.3 ppg to 9.5 ppg.;Pump tandem sweep & circ hole clean with 3 BAJ for wiper trip. 10% increase with sweep.;POOH wiper trip from 7448' to 6391' (no issues). Hole fill calc 6.4 bbis / act 7.2 bbls.;Service rig. Nlonitorwell on TT, lost .4 bbl/hr.;RiH from 6391'to 7448' (Tight spots 7068'& 7200'), W&R last stand to bottom. No fill. Disp calc 6.4 bbis / act 5 bbls, lost 1.4 bbls.;Pump sweep & circ hole clean & circ out gas. Max gas 1419 units.;Cont. drill ahead 6 3/4" production hole from 7448' to 7576, 295 gpm, 2500 psi, 5 -10 k wob, 60 - 80 rpm, 11 - 12.5 k Mbs trq, PU wt 165 k, SO wt 80 k, ROT wt 110 k.;ECD 11.2 ppg with 9.5 ppg mud. Pumping sweeps every 300'to aid in hole cleaning, average 10.25% increase in cuttings.;Trouble shoot MWD detection.;Cont. drill ahead 6 3/4" production hole from 7575' to 7733', 295 gpm, 2600 psi, 5 - 10 k wob, 60 - 80 rpm, 11 -12.5 k ft/lbs trq, PU wl 165 k, SO wt 79 k, ROT wt 110 k.;ECD 11.2 ppg with 9.5 ppg mud. Pumping sweeps as needed to aid in hole cleaning, average 10 -15% increase in cuffings.;Distance to plan: 4.45' (1.31' Low / 4.26' Left).;125 bbls solids to G&I, 647 bbis cum. 395 bbis class II fluid to G&I, 2667 bbis cum 0 bbis cement to G&I, 46 bbis cum 26 bulls mud loss down hole, 150 bbls cum 6/17/2017 Continue drilling 6-3/4" hole from 7733'm 7824'. MWD detection has worsened with little to no real time. Attempt to get survey, unable to. Rotating parameters: ROP 110 fph, 297 gpm/2850psi.;80rpms/13000 ft -lbs, ECUs 11.04 ppg, MW 9.5 ppg-;Pump low vis sweep (15% increase) followed by high vis sweep (15%) and circulate hole clean, total of 3.5 x annular volume; 290gpm/2440psi, 50rpms/12700 ft -lbs. Flow check static.;POOH from 7824'to 4395'; light at 5610' (30K), 5088' (251), 4535'(301(), 4508'(30K); wipe through tight spots easily. Observe consistent 10-20K drag from 4395' to 4366' with several 35K overpulls.;RIH one stand to 4459', establish circulation and circulate hole clean 2 x annular volume 300 gpm2420 psi, 50 rpms17800 ft-Ibs.;Continue POOH from 4459'to 4224', observe consistent drag 10-20K from 4380'to 4424' wiping clean after one pass. Observe discrepancy in hole fill - appears to be swabbing. RIH to 4584'.;Circulate hole 295gpm/2380 psi. Max gas 3528U diminishing after 2 x annular volume.;Continue to RIH to 5201' (10 stands) with no issues.;Circulate out gas; 248gpm/l865 psi. Max gas 2938 units.;Continue to RIH to 6516' with no issues.;Circulate out gas; 248gpm/1900 psi. Max gas 3357 units.;Continue to RIH to TO of 7824'. Tight spot 6890'. W&R last stand to bottom. 10' fill.;Circulate out gas; 300gpm2800 psi. Max gas 3327 units. Increase mud wt from 9.5 ppg to 9.8 ppg.;F/C (static) POOH from 7824' to 4150' (no issues) Calc hole fill 24 bits / Act 31.2 bbis, lost 7.2 bbls.;F/C (static) BROOH from 4150' to 3100' due to tight hole & attempting to swab. 250 gpm, 1900 psi, 50 rpm, 6.5 - 7 k ft/lbs trq.;81 bbis solids to G&I, 728 bbis cum. 279 bulls class II fluid to G&I, 2946 bbis cum 0 bbis cement to G&I, 46 bbls cum 21 Will mud loss down hole, 171 bbis cum 6/18/2017 Continue to back ream out of hole from 3100' to 3000'. 250 gpm/1950 psi with 150-300psi diff, 50 rpms/6600-;Change out swivel packing.;Continue to back ream out of hole from 3000' to 1540'. 250 gpm/1830 psi with 150-300 psi diff, 50rpms/5600 fl-Ibs.;Circulate 4 annular volumes until shakers clean staging pumps up to 300 gpms/2200 psi, 50 rpms/5000 ft-lbs. Flow check, static.;POOH from 1540'to 128'. Pull sources, download MWD. UD TM collar, motor and bit. Bit grade 24-DL-A-X-I-BT-DSF.;Pick up new BHA TO 109'. HDBS MM65D bit, Sperry motor with 1.5° bend, M/U MWD tools from derrick. Measure RFO = 0.85/4.72 = 64.8'. WU new TM collar, upload MWD. Load sources, shallow pulse test.;RIH BHA #4 from 109'to 3900' no issues.;Circulale B/U, 228gpm/1175 psi. 50 rpm, 7 k Mbs trq. Max gas 56 units.;Cont. to RIH from 3900' to 7824'. No issues & no fill. Calc disp 51.8 bbls /Act disp 46.94 bbls.;Pump sweep, circulate & cond , 247 gpm / 1525 psi. 50 rpm, 13 k ft/lbs trq. Max gas 692 units.;Ccnt. drill ahead 6 3/4" production hole from 7824' to 7920', 248 gpm, 1550 psi, 5 -10 k wob, 60 - 80 rpm, 12 -13.5 k fl/lbs trq, PU wt 180 k, SO wl 80 k, ROT wt 114 k.;ECD 10.8 ppg with 9.8 ppg mud.;Distance to plan: 3.64' (3.09' Low / 1.91' Left).;0 bills solids to G&I, 728 bbls cum. 0 bbls class II fluid to G&I, 2946 bbis cum 0 bbls cement to G&I, 46 bbis cum 23 blils mud loss down hole 94 bbls cum 6/19/2017 Continue drilling 6-3/4" hole from 7920'to 8283', no slides. Rotating parameters: ROP 60-120 fph, WOB 7-111K, 250 gpm/1852 psi, 80 rpms/15400 psi. ECD 10.65ppg with 9.8 ppg mud.;Continue drilling 6-3/4" hole from 8283' to 8573', sliding as needed, MAD pass all slides. Sliding parameters: ROP 30401ph, WOB 2-SK, 250gpm/1700 psi with 100psi diff.;Rotating parameters: ROP 60-120 fph, WOB 7-11K, 250 gpm/1852 psi, 80 rpms/15700 psi. ECD 10.65.;Cont. drill ahead 6 3/4" production hole from 8573' to 9198', 250 gpm, 1750 psi, 8 - 12 k wob, 60 - 80 rpm, 16 - 17.5 k ftllbs irq, PU wt 220 It, SO wt 90 k, ROTVA 130 k.;ECD 10.9 ppg with 9.8 ppg mud. Pumping sweeps as needed to aid in hole cleaning. 30 - 50% increase in cuttings.;Distance to plan: 22.01' (20.03' Low / 8.5' Leh).;108 bbis solids to G&I, 836 bbls cum. 342 bbls class II fluid to G&I, 3288 bbls cum 0 bbls cement to G&I, 46 bbls cum 23 bbls mud loss down hole 217 table cum 6/20/2017 Cont drilling 6314" hole from 9198' to TD at 9265'. ROP 100 fph, 250gpm/2146psi, 80 rpms/17500 fl-lbs WOB 8.12K. PU M 132 k, SO VA 90 k, ROT wt 134 k.;Distance to Plan: 33.08' (31.46' low 110.24' right).;Pump high viscosity sweep (25%) and circulate hole clean 3 additional annular volumes; 250gpm/1880 psi, 80rpms/16700 tt-Ibs, reciprocating pipe. Flow check, static.;POOH from 9266 to 7500"; tight spots at 8681' (40K), 8627' (30K), 8490 (30K), 8240-8200 (30K). Attempt to work through tight spots, unable to. Wash through 200 gpm/1400 psi with 100-200 diff.;Circ BN, 252 gpm, 1623 psi, 60 rpm, 16 k ft/lbs trq. Max gas 146 units (good amounts of sand & coal chips on B/U) PU wt 120 k, So w196k.;Service rig. C/O grabber dies.;RIH from 7500' to 9265'. (no issues). W&R last stand to bottom.;Pump 40 bbis tandem sweep & circ hole clean, 258 gpm, 1974 psi, 50% increase in cuttings. Max gas 393 units.;Pump out of hole 5 stands from 9265' to 8945'. F/C (static) POOH on elevators fro 8945' to 7 5/8" casing shoe @ 1419'. (Few tight spots 8809', 7449 ,7356', 6894', 6330', 5543' work thru once/clear).;F/C (static). Cont. to POOH on elevators from 1419' to 109' (rack back HWDP, jars & Flex collars) Calc hole fill 60.4 bbls / Act hole fill 79.5 bbls.;PJSM. Remove sources & up-load LWD data. UD BHA. Bit grade: 1-1-ER-G-X-1-NO-TD.;77 bbls solids to G&I, 913 bbls cum. 103 bible class II fluid to G&I, 3391 bbls cum 0 bbls cement to G&I, 46 bbis cum 23 bbis mud loss down hole, 240 bbis cum 6/21/2017 LD mud motor, MU 6 3/4" tri-cone, bit sub and stabilizer to be staged on rig floor. Clean and clear rig floor.;Spotted a-line unit and held PJSM with rig crew and SLB a-line crew. RU sheaves and MU 4.5" OD drift assembly.;RIH on e-line and set down at 4870' numerous times. PU clean, no sticking but cannot get past 4870' (sand/sandstone). Notified Geo and decision made to run the XPT assembly. POOH and swapped tools.;RIH and XPT failed prior to exiting casing shoe (1419). POOH and MU backup XPT assembly.;RIH and set down at 4870'. Worked a couple limes and got through. RIH to 8900' with little issue. Pulled up hole to 8772' and start obtaining RFT's up to 8152'.;Cont obtaining RFT's from 8152'to 4320' (Rig crews working on PM's & housekeeping around the rig) Monitor well on trip lank;Cont obtaining RFT's from 4320'to 2378' (Rig crews working on PMs & housekeeping around the rig) Monitor well on trip tank;0 bbls solids to G&I, 913 bbls cum. 0 bbls class II fluid to G&1, 3391 bbis cum 0 bbis cement to G&I, 46 bbis cum 12 bbls mud loss down hole 252 bbis cum 6/22/2017 Cont obtaining RFT's from 2378'to 1692', then POOH to surface and LD XPT tool string. 99 samples total taken at 99 stations.;MU SWC assembly and function test same (OK). RIH and set down at 6480' (bottom of a slide). Notify Geo and decision made to start core sampling at 6426'. Obtain SWC's from 6426'to 1569,;POOH to surface, LD tools and check same. Obtained 2 decent cores due to tool being jammed with coal chips and wall cake. Notify Geo, decision made to make ECS run and possibly SWC run after that.;Shipped out Sperry tools and received tree and packoff assembly. Had rig visit by Asset Team Leader Chet Starkel and Area Ops Manager Chad Helgeson. Well taking just over 1/2 bph on trip tank.;MU HNGS-ECS assembly and load RA source. RIH to 6480'& tag up on bridge. Make several attempts to work past with no success.;POOH from 6480' while logging @ 750 fi to 14191. RIH to 2300'& repeat pass 200' of logs;9 bills solids to G&I, 922 bbis cum. 81 bbls class II fluid to G&I, 3472 bbls cum 0 bbis cement to G&I, 46 bbis cum 12 bills mild loss down ole 264 bbls cum 6/23/2017 Cont POOH on a-line from 1419' to surface, held PJSM and removed RA source. LD ECS assembly and MU SWC assembly, function lest same (OK).;RIH to 6400' and start obtaining cores. Tool jammed up again, POOH and check care tube. Recovered 8 good cores. Notified Geo and decision made to run PNX tool and end a-line work. SWC tool was;packed with clay and coal chips, and had a marker disc jammed under coring bit.;LD SWC assembly, MU LEH-PNX assembly and RIH. Tagged up again at 6480' numerous times with no overpulls. Started logging up hole at 1,000 ft/hr from 6480'to 5800'.;Cont logging open hole with LEH-PNX tool from 5800'to 1419';POOH with LEH-PNX tool & UD same. R/D SLB E-Iine;Service rig;M/U 6 3/4" clean out BHA & RIH to 1307';Circ & cond mud with 220 gpm, 225 psi, Max gas 8 unils;Slip & cut drill Iine.;Cont. tripping in hole from 1307' to 2247';0 bbls solids to G&I, 922 bbls cum. 0 bbls class II fluid to G&I, 3472 bbis cum 0 bbls cement to G&I, 46 bbis cum 13 bible mud loss down hole, 277 bills cum 6/24/2017 Cont TIH from 2247' to 3297'.;MU topdrive and CBU one time at 248 gpm-414 psi, 30 rpm-5700 ft/fibs off bott torque. Max of 37 units gas at bottoms up.;Cont TIH from 3297' to 6352' filling pipe every 15 stands.;MU topdrive and fill pipe. CBU one time at 211 gpm-614 psi, 80 rpm-11,400 ft/lbs off bott torque. Max of 806 units at bottoms up.;Cont TIH from 6352' to 9015' filling pipe every 15 stands. Did not see anything at 6480' where a-line set down multiple times. Had two tight spots at 6630' and 6680' that we worked a couple times on;elevators and saw nothing. At 7800' we had to MU topdrive and wash ream down to 7847' and at 8775 MU topdrive and washed reamed down to 8781'. At 9015' we set down again multiple times.;MU topdrive at 9015', filled pipe then washed reamed down to 9023'. Gas increased to 3490 units. Cont to circ out gas at 188 9pm450 psi, 65 rpm-14,800 fl/lbs off bolt torque.;Cont TIH from 9023' and MU topdrive on last stand. Filled pipe and washed to bottom with no flil.;Pumped hi-vis nutplug sweep around at 251 gpm-1000 psi, 80 rpm-16,000 fl/lbs off bott torque. Had a max of 280 units at bottoms up and 20% increase in coal chips and sand.;With sweep to surface had a 25% increase in cuttings to surface. Did a second circulation while rotating and reciprocating.;Pulled 10 stands and racked back in derrick, up to 8904'. Up wt 260K. Flow check at 8904' = static. Pumped 10 bbl dry job.;Cont to POOH and LD singles from 8904' to 4586. Tight hole & not able to work thm;W&R thru tight spot @ 4586' with 250 gpm, 620 psi, 50 rpm 7.5 k fUlbs trq. Cont. to circ B/U;Pumped 8 bbl dry job.Cont to POOH and LD singles from 4586'to 1000';14 bbls solids to G&I, 936 bbis cum. 76 bbls class II fluid to G&I, 3548 bola cum 0 bbls cement to G&I, 46 bbls cum 13 bbls mud loss down hole, 280 bbis cum I 6/25/2017 Cont to POOH LD singles (4 1/2" DP) from 1000' to 379'. TIH from derrick remaining DP to 950'. Pumped last of dry job, POOH LD DP, HWDP, jars, stab, bit sub and cleanout bit.;Clean and clear rig floor, drain BOP stack, RU and pull wear ring, set test plug, flooded stack and surface lines, purged air and shell tested. Witness of BOP test was waived by AOGCC Rep Jim Regg;on 6-24-17 at 19:54 hrs.;Tesl all BOPE at 250 low, 3500 high at min low and 10 min high. Tested annular at 250/2500 psi. Total Safety tested then calibrated all gas alarm equipment. C/O to long bails while testing.;Drained BOP stack, pulled wear ring, dummy ren hanger, hung casing elevators, closed annulus valve and filed hole, staged slips and RU fill up Iine.;RU casing tongs and air slips. Staged casing on pipe racks. Held PJSM with Weatherford crew and rig crew.;MU shoe track, filled same and checked floats (OK), cont PU single in hole with 4 1/2" TXP casing to 2985';Circ & cond mud with 200 gpm, 190 psi, PU w140 k, SO wt 35 k;Cont PU single in hole with 4 1/2" TXP casing from 2985' to 5553';Circ & cond mud with 205 gpm, 338 psi, PU wt 66 k, SO wt 48 k;Cont PU single in hole with 41/2" TXP casing from 5553' to 6900';3bbls solids to G&I, 939 bbis cum. 62 bbis class II fluid to G&I, 3610 bbis cum 0 bbls cement to G&I, 46 bbis cum 12 bbis mud loss down hole, 292 bbis cum 6!26/2017 Cont to PU single in hole with 4112" TXP 12.6# L-80 casin from 6900' to 9231' MU landing jnt, SO and land hanger with no issues. Shoe at 9254'. Load plugs and MU plug launcher on landing jnt.;MU circ lines and pick hanger Toff seat. Up wt 134K, dwn wt 70K. We were 5.4 bbis under calculated on casing displacement for entire run.;Broke circ at 3 bpm, staging up to 5 bpm -627 psi. Did not reciprocate due to tight tolerance of hanger inside BOP stack. Had a max of 329 units gas at bottoms up. Cont to spot cementers equipment and;RU hardline to rig floor, and held PJSM with Halliburton cementers, Peak drivers and rig team while circulating surface to surface. Shut down rig pump and lined up on pump unit.;Halliburton pressure tested lines at 590 low 4160 high, good tests. Halliburton pumped 31 bbis of 12 ppg Clean Spacer III at 3.5 bpm, 430 psi and shut down. Halliburton drooped bottom plug and pumoed240 bbis (675 sx) 12 5 ppg Tvpe-II cement at 4 bora 270 psi follow d with 32 bbis (160 sx) 0115 3 ppg Class G Tail cement at 4 5 bono 184 pet. Halliburton dropped lop plug, then displaced with 10,bbls fresh water, followed by 129 bbis 6% KCL at 6 bpm, 2200 psi. Slowed to 3 bpm with 10 bbis to Started higher go. seeing PH of 11.5 in returns 727 bbis into displacement, stared overboard retums.;Dumped approximately 3 bbis good spacer.We did bump the plug (calc = 139.4 bbls, actual = 139 bbis) and held 3200 psi (FCP 2300 psi at 3 bpm) for 3 minutes, bled off and floats held. Bled back 1.5;bbls to truck. Had no cement to surface. WeIlLife 1044 was added at 1!2 ppb, to both lead and tail. Mix water temp = 70 deg. Pumped 35 % excess on both lead and tail. Did not reciprocate the string;due tight tolerance of hanger in BOP stack. Held hanger 2' ott seat throughout the job. Lost 63 bbis throughout the job. Up wt 134K, dwn wl 70K prior to landing hanger. TOC +/- 1077' (342' up inside;surface casing). CIP at 13:06 pm, 6-26-17. CIea11C?up, RD and released Halliburton.;Cleaned up, RD and released Halliburton. Started hauling off mud from pits.;BO landing jnt, MU packoff assembly fo that and landed same. Pulled lockdown pin and verified landing. RILD's. Tested packoff at 500!5000 psi 2 minutes each.;Removed casing elevators and long bails, removed shaker screens and start cleaning pits from top down. Blew down topdriva and mud lines through pumps. Flush pumps wlwater.;Removed rig tongs from Poor. Canrig RD their shack.;W.O.C. Clean out cellar. Break out saver sub. LID top drive. Clean out under shakers & possum belly. Clean mud pumps;Cont. W.O.C. RID flow line & flow box. Install shipping beams. Cont. to clean mud pits. Prep derrick to be laid down. Roll up third parry lines & Pason lines;19 Ionia solids to G&I, 958 bbls cum. 946 bbis class II fluid to G&I, 4556 bbis cum 0 bbis cement to G&I, 46 bbis cum 0 bbis mud loss down hole, 292 bbis cum 6/27/2017 Offload last of mud from pits and cont cleaning pits. Disconnect Pason lines, electrical cords, RD centrifuge, ship out pipe tubs and mad loads to Swanson Received 988 gallons fuel.;RU test chart on kill line, flood test hoses and stack, purge air, close blinds. Pressure test 4 1/2" casing at 3500 psi for 30 minus. on chart. Good test. Bleed off and drain stack. Install BPV.;ND choke line, kill line and BOP stack.. Crane on location at 14:30. Lay over beaver slide, spot crane and remove BOP stack from cellar, place in cradle for move.;Stage tree in cellar and NU same. Lay down poor boy degasser, ship out cement silo, pick centrifuge from stand, Total Safely RD gas detection equipment. Pull windwalls from pit walls and store in;connex. Tested neck seals on hanger at 500 psi f/5 min, then 5,000 psi f/5min. Tested void f/5min then at 5,000 f/5min. Good tests. Pulled BPV, installed 2 way check.;RU and tested tree at 5,000 psi f/5min. Good test. Pulled 2 way check. RELEASED RIG AT 18:00 hrs on 6-27-17;;0 bbis solids to G&I, 958 bbis cum. 155 bbis class II fluid to G&I, 4711 bbis cum 0 bbis cement to G&I, 46 bbis cum 0 bbis mud loss down hole 292 bbis cum n Well Name: NINU Kalotsa3 Field: Ninilchik County/State: , Alaska (LAT/LONG): ovation (RKB): API #: 50-133-20661-00 Hilcorp Energy Company Composite Report Spud Date: Job Name: 1710632C Kalotsa 3 Completion Contractor AFE #: AFE $: 'Aotivit. Cate - Opa su dry.... 7/8/201 TW and JSA. Spot equipment and MU 3-1/2" Junk Basket., RIH w/3-1/2" JB and tag at 9080' KB. The tag was not correlated. SLB didn't have the game ray run with JB. POOH. No problems. Switch over the Kalotsa #4.,MU and RIH with CBL, correlate to OHL and tag at 9135'. Seems like we set down on stringer ubto with the 3-1/2" Junk basket. We couldn't get rough with junk basket due to no gauge ring on JB. The CBL tool is 1-11/16 OD. Log to 80'. Rig down CBL tool and la crane over. Will be back at 7am to run PNX log. 7/20/2017 Obtain PTW. Hold safety meeting. Discuss job procedure and review JSA with crew.,MIRU SLB CTU 13 with 1.75' CT. Hook field triplex to IA. (7-5/8"x4- 1/2") 400 psi out of fluid. Waft for production operator to fill triplex. Continue to pressure up to 2500 psi. Bleeding down. Bleed back to tank and allow air n/ to escape. Repeat 3 times. Pressure dropping less each tinrl BOPE test witness notification sent 7119/17 @ 12:24PM. Witness waived by Jim Regg N 7/19/17 @ 12:29 PM. StartBOPE test. Accumulator draw down test. Test all rams and valves 250-300 psi Low and 4000 psi high. BOPE test complete.,Pressure up IA to 2630 psi for 30 minutes. End pressure 2500 psi. 130 psi loss over 30 minutes. Less than 5% losses over test time.,Bleed IA down to tank. Pressure up IA to 2678 psi. Shut in. Leave coil Cat acquisition running throughout the night to monitor and record IA pressure. Locations secure. SDFN. 7/21/2017 Obtain PTW. Hold safety meeting. Review and discuss job procedure. Air liquid N2 transport on location with 6002 gallons of N2.,Pressure up IA to 2700 . Shut in and monitor pressure in CT ops cab. Pick injector head. Stab 10' lubricator. Make up BHA and ball drop nozzle for reverse N2 lift. Stab on well. PT stack 250/4000 psi. Bleed down. Open master swab 23.5 turns. RIH . Start cooling down N2,Online N2 down CT annulus. 800 sof/min @ 3500' CTMD. Walk up rate slowly to 1500 scf/min. Tag PBTD @ 9142' CTMD/ 9149' RKB corrected depth. Started seeing returns to surface at 8,800' CTMD. WHP 2300 psi. Circ 23.,Stay on bottom lifting fluid with N2. WHP peak was 3450 psi. Tank strapped shows 147 labls in return tank. Well blown dry. Continue to pump for 10 minutes while N2 at surface.,Shut in choke and start POOH while pressuring up well to 3000 psi. 187,000 scf/2,008 gal for unloading well bore fluid. 81,000 scf/870 gallons used to pressure 4.5" tubing up to 3000 psi. Total fluid returned 147 bbls. Total N2 pumped 268,000 scf. or 2,878 gallons. Shut down N2. Continue to POOH to sudace.,Tagged up. Close master/ swab. Final SITP 3090 psi. Bleed down N2. RIG DOWN slb ctu 13 and move to Kalotsa #4. t- -P4-T-r- 7/27/2017 TW and JSA. Rig up lubricator and MU 1-11/16" Press/Temp tool. PT to 250 low and 3500 psi high. TP - 2988.5 psi.,RIH with Press/Temp tool and tie in to OHL. Tagged at 9148' and found fluid level at 9141. POOH, RIH w/2 -7/8'W' HC, 1 spf, 60 deg phase and tied into OH L. Ran correlation log and send to town. Get ok to cert from 9022' to 9026'. Spotted and fired gun with 2961.1 psi on tubing and after five minutes pressure was 2960.7. POOH. All shots fired and gun was dry., Re head line. RIH w/3 -3/8"x11' HC Razor, 6 spill, 60 degree phase and tie into OHL. Run correlation log and send to town. Get ok to pert from 9022' to 9033'. Spot and fired gun with 2847.1 psi on well. After 5 min TP was 2848. The reason TP was -100 less than first run was mainly due to we pressured up Kalotsa 2 with N2 to 2000 psi oft of 3 to pull the plug at 500'. POOH. All shots fired and gun was dry.,Rig down lubricator and move to Kalotsa #2. TP -2835.8 psi 8/25/2017 RU HES a -line. Stab on well. PT stack 3500 psi. RIH with GPT/CCL to look for fluid level. Found fluid level 77' lower than wednesday PT survey. Fluid was at 8302' Called town to discuss. (previous fluid level 2 days earlier was 8226) Flow Kalotsa 4 and regroup for N2 on Kalotsa . Monday SLB N2 pressure up to 4k., Rig back equipment. 2620 SITP. SDFN. location secure. NOTE: Started attempting to push fluid away by shutting in Kalotsa #4 production and jumping pressure to Kalotsa # 3 at 15:00 hrs 8/24117. Fluid level at that time was 8225' MD. WHP on K-3 when started build up was 180 psi until we tagged fluid 8302' 8/25/17 @ 12:30. 21.5 hours of pressure build pushed fluid 77' into formation. Formation is ti ht. 8/28/2017 Obtain PTW. Hold safety meeting and discuss job procedure and pressure Iimitations.,MIRU SLB N2 Float. Transfer N2 from Air Liquid transport. Cool down N2 pump. Rig up 1502 iron. (1502 N2 iron rigged to HES wire line valve 1502),PT stack to 250/4500 psi. Bleed down. Open well. Initial WHP 2610 psi. (pressure build from Kalotsa #4). Online with N2 at 800 scf/min at 0830. Average N2 temp 100•F. 0925 hrs WHP/pump pressure 3800 drop N2 rate to as slow as it can pump. 400 scf/min . Pressure still climbing. Shutdown N2 at 4060 psi @0930. Well shut in. Monitoring pressure.,1.5 hours WHP still 4030 psi. Holding like a rock. Doesn't look like we are pushing fluid away very fast. Formation is tight. Online with N2 pressure up well to 4200 psi, shut down N2. 11:15 hrs. Shut in Swab, Upper and lower master valves. Final SITP 4206 psi. Rig down SLB N2 pump. Total N2 pumped. 62,000 scf or 665 gallons. 3000 gallons of N2 available.,Weil was shut in at 11:15 hrs. Prior to departing location at 12:10 WHP was still 4206 psi. Plan forward is to let well sit for up to one week and attempt PT/survey to check for fluid level. 8/31/2017 PTW and JSA. Rig up lubricator. PT to 250 psi low and 4500 psi high., RIH w/Press/Temp Tool and tie into pert log. Tagged 9164'. Found fluid level at 8982'. POOH.,Rq down lubricator and turn well over to field. 911 012 01 7 Mobs to location. PTW and JSA. Rig up Lubricator. PT to 250 psi low and 4500 psi high.,RIH w/3.74" CIeP and tie into OHI Run correlation log and send to town. Get ok to set plug at 9012'. Spotted plug and set at 9012'. Lost 180 lbs of line tension. Pick up 30' and go back and tag plug. POOH. Good set. TP - 3000 d psi when plug was set.,RIH w/3 -1/2"x20' bailer f lied with 4 gals of cement (7') and tag plug at 9012'. Pick up and dump cement on plug. Lost 30 lbs line 1 tension when cement dumped. POOH. Good dump. Est TOC 900T. C I P is 1230 hrs.,Rig down lubricator and WOC. Spot up on Kalotsa 4 for ped job in the morning. 912612017 Mobe to location. PTW and JSA. Rig up Lubricator. PT to 250 psi low and 4500 psi high. TP - 2400 psi, R I H w/GPT tool, tie into OHL and tag at 9008'. Found fluid level at 9004' with 2400 psi on well. POOH.,RIH w/2-718"X20' Razor HC, 6spf, 60 deg phase pelf gun, tie into OHL. and tag at 9008'. Run correlation log and send to town. Bleed well down to 2234 psi. Get ok to perforate from 8975' to 8995'. Spotted gun and fired with 2234 psi on tubing. After 5 min pressure was 2235.2 psi, 10 min was 2234.8 psi and 15 min - 2234.1 psi. POOH. All guns fled and gun was wet., Rig down lubricator and turn well over to field. Hilcorp Alaska, LLC Ninilchik Unit Kalotsa Kalotsa 3 50133206610000 Sperry Drilling Definitive Survey Report 21 June, 2017 HALLIBURTON Sporry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Kalotsa 3 Project: Ninilchik Unit TVD Reference: KaIDtSa 3 WP05 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 3 WP05 @ 144.50usft Wall: Kalotsa 3 North Reference: True Wellbore: Kalolsa 3 Survey Calculation Method: Minimum Curvature ' Design: Kalotsa 3 Database: Sperry EDM - NORTH US + CANADA roject Ninilchik Unit lap System: US State Plane 1927 (Exact solution) • System Datum: Mean Sea Level neo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Well Kalotsa 3 Kalotsa 3 Magnetics Model Name Sample Date Well Position +N/.S 0.00 usft Northing: 2,233,535.94 usft ° Latitude: 60° 6' 15.475 N +E/ -W 0.00 usft Easting: 209,857.66 usft ° Longitude: 151° 35'24.2&4 W Position Uncertainty 0.00 usft Wellhead Elevation: 144.50 usft Ground Level: • 126.50 usft Wellbore Kalotsa 3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength Map (9 M (nT) MD BGGM2017 6/5/2017 An 15.67 73.11 55,145 TVDSS +N/ -S +E/ -W Northing Design Kalotsa 3 Section Audit Notes: (') (°) (usft) Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 18.00 (usft) (usft) (usft) (I -126.50 18.00 0.00 0.00 342.19 Survey Program Date 6/21/2017 0.00 UNDEFINED From To 56.58 202.41 (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 202.41 1,387.92 MWD+SC+sag (1) (Kalotsa 3) MWD+SC+sag Fixed:v2:standard der,& axial Correction +sag 05/26/2017 1,438.14 9,228.73 MWD+SC+sag(2)(Keloaa 3) MWD+SC+sag Fixed:v2:standard dec& axial correction + sag 06/12/2017 87.D2 0.71 0.94 2,233,536.83 621/2017 5:26:09PM Page 2 COMPASS 5000.1 Build 81 Map Map Vertical MD Inc An TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (') (°) (usft) (usft) (usft) (usft) (it) (ft) (°1100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -126.50 D.00 0.00 2,233,53594 209,857.66 0.00 0.00 UNDEFINED 202AI 0.49 56.58 202.41 57.91 0.43 0.66 2,233,536.36 209,858.33 0.27 0.21 MWD+SC+sag(1) 231.53 1.07 41.16 231.52 87.D2 0.71 0.94 2,233,536.83 209,858.61 2.10 0.39 MWD+SC+sag(1) 292.67 3.58 341.46 292.62 148.12 2.95 0.71 2,233,538.87 209,858.44 5.20 2.59 MWD+SC+sag(1) 35446 5.90 334.08 354.19 209.69 7.63 -1.29 2,233,543.69 209,856.55 3.87 7.66 MWD+SC+sag(1) 414.96 9.24 332.48 414.15 269.65 14.74 4.90 2,233,550.80 209,853.12 5.53 15.53 MWD+SC+seg(1) 476.84 11.66 330.52 475.00 330.50 24.59 -10.27 2,233,560.77 209,847.98 3.95 26.55 MWD+SC+sag(1) 538.06 13.05 326.91 534.81 390.31 35.77 -17.09 2,233,572.11 209,841.43 2.60 39.28 MWD+SC+sag(1) 599.96 14.50 328.58 594.92 450.42 48.24 -24.94 2,233,584.76 209,833.88 2.43 53.55 MWD+SC+sag(1) 66370 17.12 329.55 656.25 511.75 63.14 -33.86 2,233,599.87 209,825.33 4.13 70.47 MWD+SC+sag(1) 725.79 1915 332.22 715.23 570.73 80.07 4326 2,233.617.03 209,816.33 3.68 89.47 MWD+SC+sag(1) 787.91 21.72 332.37 773.42 628.92 99.32 -53.37 2,233,636.52 209,806.69 3.98 110.88 MWD+SC+Sag(1) 849.94 23.59 333.72 830.66 686.16 120.62 -64.19 2,233,658.07 209,796.39 3.13 134.47 MWD+SC+sag(1) 621/2017 5:26:09PM Page 2 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hill Alaska, Ninilchik Unit Kalotsa Kalotsa 3 Kalotsa 3 Kalotsa3 LLC Local Co-ordinate Reference: Well Kalotsa 3 TVD Reference: Kalotsa 3 WP05 @ 144.50usft MD Reference: Kalotsa 3 WP05 @ 144.50usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US+CANADA Survey Map Map vertical MD Inc Act TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (H) (°/100') (ft) Survey Tool Name 912.71 25.00 334.93 887.87 743.37 143.90 -75.37 2,233,681.61 209,785.7/ 2.38 160.05 MWD+SC+sag(1) 975.68 26.83 335.23 944.51 B00.01 168.85 -86.96 2,233,706.84 209,774.78 2.91 187.36 MWD+SC+sag(1) 1,037.96 28.75 335.70 999.60 655.10 195.27 -9902 2,233,733.54 209,763.37 3.10 216.20 MWD+SC+sag(1) 1,100.55 31.12 336.56 1,053.84 909.34 223.83 -111.65 2.233,762.39 209,751.43 3.85 247.25 MWD+SC+sag(1) 1,162.66 33.39 337.44 1,106.36 961.86 254.35 -124.59 2,233,793.21 209,739.22 3.73 280.26 MWD+SC+sag(1) 1,225.19 34.76 338.96 1,158.15 1,013.65 286.87 -137.59 2,233,826.04 209,727.01 2.58 315.21 MWD+SC+sag(1) 1,287.80 35.50 339.29 1,209.36 1,064.86 320.54 -150.43 2,233,860.00 209,714.98 1.22 351.19 MWD+SC+sag(1) 1,349.61 35.08 340.65 1,259.81 1,115.31 354.08 -162.66 2.233,893.83 209,7113.56 144 386.87 all (1) 1,387.92 34.88 341.62 1,291.20 1,146.70 374.87 -169.76 2,233,914.78 209,696.96 1.54 408.82 MWD+SC+sag(1) 1,43B.14 34.34 342.32 1,332.54 1,186.04 401.99 -176.59 2,233,942.11 209,688.79 1.34 437.35 MWD+SC+sag(2) 1,501.25 35.09 341.57 1,384.41 1,239.91 436.16 -189.73 2,233,976.54 209,678.47 1.37 473.29 MWD+SC+sag(2) 1,563.57 35.52 340.82 1,435.27 1,290.77 4T0.25 -201.34 2,234,010.90 209,667.69 0.98 509.30 MWD+SC+sag(2) 1,627.17 35.91 340.49 1,486.91 1,342.41 505.28 -213.64 2,234,046.21 209,656.23 0.68 546.41 MWD+SC+sag(2) 1,688.88 34.36 339.70 1,537.37 1,392.87 538.67 -225.73 2,234,079.89 209,644.95 2.62 581.90 MWD+SC+sag(2) 1,751.23 34.23 339.35 1.588.88 1,444.38 571.59 -238.02 2,234,113.09 209,633.46 0.38 616.99 MWD+SC+sag(2) 1,812.57 34.56 338.97 1,639.50 1,495.00 603.97 -250.34 2,234,145.76 209,621.92 0.64 651.59 MWD+SC+sag(2) 1,875.20 34.80 338.90 1,691.00 1,546.50 637.22 .263.15 2,234,179.31 209,609.91 0.39 687.17 MWD+SC+sag(2) 1,937.95 35.10 339.31 1,742.44 1,59194 670.81 -275.97 2,234,213.19 209,597.90 0.61 723.07 MWD+SC+sag(2) 2,000.00 35.37 338.63 1,793.12 1,648.62 704.22 -288.82 2,234,246.90 209,585.86 0.77 758.81 MWD+SC+sag(2) 2,061.51 33.32 339.39 1,843.90 1,699.40 736.61 -301.26 2,234,279.59 209,574.21 3.40 793.46 MWD+SC+sag(2) 2,123.69 33.46 339.59 1,895.82 1,751.32 768.67 -313.25 2,234,311.92 209,563.DD 0.29 827.64 MWD+SC+sag(2) 2,186.05 34.10 339.63 1,947.65 1,603.15 801.17 -325.33 2,234,344.70 209,551.70 1.03 862.27 MWD+SC+sag(2) 2,247.79 34.54 338.88 1,998.64 1,854.14 833.72 -337.66 2,234,377.54 209,540.16 0.99 897.04 MWD+SC+sag(2) 2,310.38 35.00 338.64 2,05D.06 1,905.56 866.99 -350.59 2,234,411.11 209,528.03 D.77 932.67 MWD+SC+sag(2) 2,371.58 33.84 339.67 2,100.54 1,955.04 899.31 -362.90 2,234,443.72 209,516.50 2.12 967.21 MWD+SC+sag(2) 2,432.06 34.01 339.73 2,150.72 2,005.22 930.9T -374.61 2,234,475.65 209,505.55 0.29 1,000.93 MWD+SC+sag(2) 2,495.94 35.01 339.57 2,203.36 2,058.86 964.90 -387.20 2,234,509.BB 209,493.79 1.57 1,037.09 MWD+SC+sag(2) 2,557.78 35.55 339.69 2,253.85 2,109.35 998.39 -399.63 2,234,543.65 209.482.16 0.88 1,072.77 MWD+SC+sag(2) 2,62D.33 34.36 341.18 2,305.11 2,160.61 1,032.15 411.64 2,234,57].69 209,470.9T 2.34 1,108.59 MWD+SC+sag(2) 2,681.95 34.83 340.91 2,355.64 2,211.34 1,065.24 423.00 2,234,611.04 209,460.41 0.813 1,143.57 MWD+SC+sag(2) 2,744.18 35.33 340.85 2,406.76 2,262.26 1,099.03 434.72 2,234,645.11 209,449.51 0.81 1,179.32 MWD+SC+sag(2) 2,807.60 33.83 341.93 2,458.98 2,314.48 1,133.14 -446.21 2,234,67948 209,438.84 2.55 1.215.31 MWD+SC+sag(2) 2,870.11 34.00 341.83 2,510.85 2,366.35 1,166.28 -057.06 2,234,712.88 209,428.80 0.29 1,250.19 MWD+SC+sag (2) 2,931.22 34.66 342.08 2,561.32 2,416.82 1,199.05 467.73 2.234,745.90 209,416.91 1.10 1,284.65 MWD+SC+sag(2) 2,994.98 35.03 341.22 2,613.64 2,469.14 1,233.63 -479.20 2,234,780.74 209,408.28 0.96 1,321.08 MWD+SC+sag(2) 3,056.78 35.25 340.85 2,664.18 2,519.68 1,267.27 <9D.76 2,234,814.65 209,397.53 0.50 1,356.64 MWD+SC+sag(2) 3,117.97 35.45 340.43 2,714.09 2,569.59 1,300.67 502.50 2,234,848.32 209,386.60 0.51 1,392.03 MWD+SC+sag(2) 3,180.69 35.89 340.83 2,765.D4 2,620.54 1,335.17 -514.63 2,234,883.10 209,375.30 0.79 1,428.59 MWD+SC+sag(2) 3,242.65 34.30 341.78 2,815.74 2,671.24 1,368.91 -526.05 2,234,917.11 209,364.70 2.71 1,464.21 MWD+SC+sag(2) 3,305.30 34.20 341.58 2,867.52 2,723.02 1,402.38 -537.13 2,234,95084 209,354.42 0.24 1,499.46 MWD+SC+sag(2) 621/2017 5:26:09PM Page 3 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Kalotsa 3 Project: Ninilchik Unit TVD Reference: Kalotsa 3 WP05 @ 144.50usft Site: Kalolsa MD Reference: Kalotsa 3 WPO5 @ 144.50usft Well: Kalotsa 3 North Reference: True Wellbore: Kalotsa3 Survey Calculation Method: Minimum Curvature Design: Kalotsa 3 Database: Sperry EDM - NORTH US +CANADA Survey Map Map Vertical MD Inc Azi TVD NDSS +N/.S +FJ -W Northing Fasting. DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,367.87 34.60 340.63 2,919.15 2,774.65 1,435.83 -548.58 2,234,984.55 209,343.78 1.07 1,534.81 MWD+SC+sag(2) 3,429.01 34.59 339.97 2,969.48 2,824.98 1,468.51 -560.28 2,235,017.50 209,332.87 0.61 1,569.50 MWD+SC+sag(2) 3,491.47 34.59 339.04 3,020AD 2,876.40 1,501.72 572.70 2,235,051.00 209,321.26 0.85 1,604.92 MWD+SC+sag(2) 3,553.38 34.79 338.02 3,071.81 2,927.31 1,534.51 385.59 2,235,084.09 209,309.15 0.99 1,640.08 MWD+SC+sag(2) 3,615.47 34.79 337.19 3.122.80 2,978.31) 1,567.27 -599.09 2,235,117.16 209,296.45 0.76 1,675.39 MWD+SC+sag(2) 3,677.58 34.08 339.39 3,174.D3 3,02953 1,599.89 -612.09 2,235,150.09 209,284.24 2.31 1,710.43 MWD+SC+sag(2) 3,740.10 33.84 338.79 3,225.88 3,081.38 1,632.51 -624.55 2,235,183.00 209,272.57 0.66 1,745.30 MWD+SC+sag(2) 3,802.60 33.48 341.04 3,277.90 3,133.40 1,665.04 -636A5 2,235,215.81 209,261A6 2.08 1,779.91 MWD+SC+sag(2) 3,864.10 34.74 341.36 3,328.82 3,184.32 1,697.69 -647.56 2,235,248.71 209,251.13 2.07 1,814.39 MWD+SC+sag(2) 3,926.53 35.94 340.87 3,379.75 3,235.25 1,731.86 -659.25 2,235,283.15 209,240.27 1.98 1,850.50 MWD+SC+sag(2) 3,988.12 35.75 340.39 3,429.67 3,285.17 1,765.86 -671.21 2,235,317.45 209,229.13 D.55 1,886.55 MWD+SC+sag(2) 4,049.71 36.98 340.17 3,479.27 3,334.77 1,800.26 -683.53 2,235,352.11 209,217.64 2.01 1,923.05 MWD+SC+sag(2) 4,111.36 36.82 339.52 3,528.57 3,384.07 1,835.00 -896.29 2,235,387.16 209,205.72 0.68 1,960.03 MWD+SC+sag(2) 4,173.98 36.95 338.60 3,578.66 3,434.16 1,870.11 -709.72 2,235,422.57 209,193.14 0.91 1,997.56 MWD+SC+sag(2) 4,235.66 35.77 339.21 3,628.33 3,483.83 1,904.22 -722.88 2,235,457.00 209,180.80 2.00 2,034.D7 MWD+SC+sag(2) 4,297.62 36.38 339.06 3,678.41 3,533.91 1,938.31 -735.88 2,235,491.39 209,168.63 0.99 2,070.50 MWD+SC+seg(2) 4,359.49 35.65 340.53 3,728.45 3,583.95 1,972.45 -748.45 2,235,525.82 209,156.88 1.83 2,106.84 MWD+SC+sag(2) 4,421.15 36.32 340.63 3,778.34 3,633.84 2,006.62 -760.49 2,235,560.27 209,145.66 1.09 2,143.96 MWD+SC+sag(2) 4,484.41 35.90 342.40 3,829.45 3,684.95 2,041.97 -772.31 2,235,595.90 209,134.70 1.76 2,180.33 MWD+SC+sag(2) 4,546.85 36.32 342.50 3,879.90 3,735.40 2,077.06 -783.41 2,235,631.24 209.124.45 0.68 2,217.13 MWD+SC+sag(2) 4,609.53 34.12 342.16 3,931.10 3,786.60 2,111.50 -794.38 2,235,665.93 209,114.31 3.52 2,253.28 MWD+SC+sag(2) 4,672.12 33.60 341.91 3,983.07 3,838.57 2,144.67 -805.14 2,235.699.36 209,104.36 D.86 2,288.15 MWD+SC+sag(2) 4,735.19 32.83 341.50 4,035.84 3,891.34 2,177.47 -815.98 2,235,732.41 209,094.31 1.27 2,322.70 MWD+SC+sag(2) 4,797.42 32.44 341.03 4,088.24 3,943.74 2,209.26 -826.76 2,235,764.44 209,084.29 0.75 2,356.25 MWD+SC+sag(2) 4,859.70 31.69 340.55 4,141.02 3,996.52 2,240.48 -837.63 2,235,795.92 209,074.17 1.27 2,389.31 MWD+SC+sag(2) 4,922.32 32.74 340.96 4,194.00 4,049.50 2,272.00 -848.64 2.235,827.69 209,063.93 1.71 2,422.68 MWD+SC+seg(2) 4,984.73 32.20 344.14 4,246.66 4,102.16 2,303.95 -858.69 2,235,859.87 209,054.65 2.87 2,456.17 MWD+SC+sag(2) 5,046.31 33.13 344.94 4,298.50 4,154.00 2,335.98 -867.54 2,235,892.11 209,046.57 1.67 2,489.38 MWD+SC+sag(2) 5,108.39 33.43 344.38 4,350.40 4,205.91) 2,368.83 -876.56 2,235,925.17 209,038.35 0.69 2,523.41 MWD+SC+seg(2) 5,169.52 31.25 345.53 4,402.04 4,257.54 2,400.41 -885.05 2,235,956.94 209,030.62 3.71 2,556.07 MWD+SC+sag(2) 5,231.36 32.27 345.71 4,454.62 4,310.12 2,431.94 -893.14 2,235,988.65 209,023.29 1.66 2,588.56 MWD+SC+sag(2) 5,293.68 33.41 345.92 4,506.98 4,362.48 2,464.70 -901.42 2,236,021.61 209,015.80 1.64 2,622.29 MWD+SC+sag(2) 5,355.97 35.01 346.37 4,558.49 4,413.99 2,498.70 -909.80 2,236,D55.80 209,008.24 2.60 2,657.23 MWD+SC+saq(2) 5,415.68 35.23 346.27 4,607.33 4,462.83 2,532.08 -917.92 2,236,089.36 209,000.92 0.38 2,691.49 MWD+SC+sag(2) 5,478.83 35.34 345.99 4,658.88 4,514.38 2,567.49 -926.67 2236,124.98 208,993.03 0.31 2,727.88 MWD+SC+sag(2) 5,540.48 35.61 345.83 4,709.09 4,564.59 2,6D2.20 -935.38 2,236,159.88 208,985.16 0.46 2,763.58 MWD+SC+sag(2) 5,603.21) 34.81 349.74 4,760.34 4,615.84 2,637.52 -943.04 2,236,195.38 208,978.35 3.81 2,799.56 MWD+SC+sag(2) 5,665.46 35.05 349.73 4,811.38 4,666.88 2,672.60 -949.39 2,236,230.60 208,972.84 0.39 2,834.90 MWD+SC+sag(2) 5,726.88 33.02 348.15 4,862.28 4,717.78 2,706.33 -955.97 2,236,264.48 208,967.08 360 2,869.03 MWD+SC+seg(2) 5,791.08 33.71 348.97 4,915.88 4,771.38 2,740.93 -962.97 2,238,29924 208,960.91 1.28 2,904.11 MWD+SC+sag(2) 612112017 5:26:09PM Page 4 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Kalotsa 3 Project: Ninilchik Unit TVD Reference: Kalotsa 3 WP05 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 3 WPO5 @ 144.50usft Well: Kalotsa 3 North Reference: True Wellbore: Kalotsa 3 Survey Calculation Method: Minimum Curvature Design: Kalotsa3 Database: Sperry EDM - NORTH US+CANADA Survey Map Map Vertical MD Inc Ali TVD TVDSS +NIS +E/•W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,853.87 32.86 348.63 4,968.39 4,823.89 2,774.74 -969.67 2,236,333.20 208,955.03 1.39 2,938.35 MWD+SC+sag(2) 5,916.97 33.63 348.25 5,021.16 4,876.66 2,808.63 -976.60 2,236,367.25 206,948.92 1.28 2,972.74 MWD+SC+sag(2) 5,97].64 33.89 347.51 5,071.60 4,927.10 2,841.60 -983.68 2,236,400.37 208,942.63 0.80 3,006.29 MWD+SC+sag(2) 6,040.62 33.57 346.87 5,123.98 4,979.48 2,875.70 -991.43 2,236,434.65 208,935.70 0.76 3,041.12 MWD+SC+sag(2) 6.102.65 32.61 346.11 5,175.95 5,03145 2,908.63 -999.34 2,236,467.76 208,928.59 1.69 3,074.89 MWD+SC+sag(2) 6,165.14 33.55 345.74 5.228.31 5,083.81 2,941.71 -1,007.64 2,236.501.03 208,921.09 1.54 3,108.93 MWD+SC+sag(2) 6,222.23 33.33 345.82 5,275.95 5,131.45 2,972.21 -1,015.36 2,236,531.70 208,914.10 0.39 3,140.33 MWD+SC+sag.(2) 6,291.10 33.48 344.71 5,33344 5,188.94 3,008.87 -1,025.01 2,236,568.59 206,905.34 0.91 3,178.19 MWD+SC+sag(2) 6,353.97 32.79 343.58 5,386.09 5,241.59 3,041.93 -1,034.39 2,236,601.87 208,896.75 1.47 3,212.53 MWD+SC+sag(2) 6,416.75 33.60 345.16 5,438.62 5,294.12 3,07503 -1,043.65 2,236,635.18 208,888.30 1.89 3,246.87 MWD+SC+sag(2) 6,478.96 32.78 347.74 5,490.69 5,346.19 3,108.13 -1,051.63 2,236,668.46 208,881.11 2.62 3,280.83 MWD+SC+sag(2) 6,541.96 32.57 347.34 5,543.72 5,399.22 3,141.34 -1,058.97 2,236,701.84 208,874.57 0.48 3,314.69 MWD+SC+sag(2) 6,604.68 31.20 346.07 5,596.97 5,452.47 3,173.58 -1,066.58 2,236,734.25 208,867.74 2.43 3,347.72 MWD+SC+sag(2) 6,667.67 29.90 347.43 5,651.22 5,506.72 3,204.74 -1,073.93 2,236,765.56 208,861.15 2.34 3,379.63 MWD+SC+sag(2) 6,730.77 29.33 347.02 5,706.07 5,561.57 3,235.15 -1,080.82 2,236,796.15 208,854.99 0.96 3,410.69 MWD+SC+sag(2) 6,792.81 27.67 348.32 5,760.59 5,616.09 3,264.07 -1,087.15 2,236,825.21 208.849.36 2.86 3,440.16 MWD+SC+sag(2) 6,855.60 26.67 347.36 5,816.46 5,671.96 3,292.09 -1,093.19 2.236,853.37 208,844.00 1.74 3,466.69 MWD+SC+sag(2) 6,917.23 27.11 347.68 5,871.42 5,726.92 3,319.31 -1,099.21 2,236,880.72 208,838.63 0.75 3,496.44 MWD+SC+sag(2) 6,979.81 25.65 346.83 5,927.48 5,782.98 3,346.43 -1,105.34 2,236,907.96 208.833.16 2.41 3,524.14 MWD+SC+sag(2) 7,041.01 23.53 343.94 5,983.13 5,838.63 3,371.07 -1,111.74 2,236,932.77 208,827.35 3.98 3,549.55 MWD+SC+sag(2) 7,102.76 21.52 343.96 6,040.17 5,895.67 3,393.80 -1,118.28 2,236,955.65 208,821.36 3.26 3,573.20 MWD+SC+sag(2) 7,164.75 18.97 341.13 6,098.33 5,953.83 3,414.27 -1,124.68 2,236,976.27 208,815.45 4.41 3,594.64 MWD+SC+sag(2) 7,228.26 17.54 343.07 6,158.64 6,014.14 3,433.19 -1,130.80 2,236,995.33 208,809.78 2.45 3,614.53 MWD+SC+sag(2) 7,289.85 16.39 347.13 6,217.55 6,073.05 3,450.54 4,135.44 2,237,012.79 208,805.56 2.68 3,632.47 MWD+SC+sag(2) 7,35239 15.24 346.97 6,277.72 6,133.22 3,467.15 -1,139.26 2,237,029.49 208,802.15 1.84 3,649.45 MWD+SC+sag(2) 7,414.40 15.08 347.74 6,337.57 6,19307 3,482.98 -1,142.81 2,237,045.39 208,798.88 0.41 3,665.60 MWD+SC+sag(2) 7,474.49 13.16 349.26 6,395.84 6,251.34 3,497.34 -1,145.75 2,237,059.82 208,796.39 3.25 3,680.17 MWD+SC+sag(2) 7,53711 1092 351.46 6,457.67 6,313.17 3,510.33 -1,147.96 2,237,072.86 208,794.47 3.62 3,693.22 MWD+SC+sag(2) 7,601.40 9.77 351.15 6,520.32 6,375.82 3,521.64 -1,149.70 2,237,084.21 208,793.02 1.81 3,704.52 MWD+SC+sag(2) 7,662.64 10.14 349.55 6,580.64 6,436.14 3,532.07 -1,151.48 2,237,094.68 208,791.49 0.75 3,715.00 MWD+SC+sag(2) 7,725.45 8.97 352.17 6,642.58 6,498.08 3,542.36 -1,153.15 2,237,105.01 208,790.07 1.99 3,725.30 MWD+SC+sag(2) 7,787.87 841 351.08 6,704.28 6.55918 3,551.69 -1,154.52 2,237,114.37 208.788.92 0.94 3,734.60 MWD+SC+sag(2) 7.850.99 7.91 349.79 6,766.76 6,622.26 3,560.53 -1,156.01 2,237,123.24 208,787.65 0.84 3,743.47 MWD+SC+seg (2) 7,913.3D 6.96 358.00 6,828.55 6.684.05 3,568.52 -1,156.90 2,237,131.25 208,786.95 2.28 3,751.35 MWD+SC+sag(2) 7,976.49 6.80 359.41 6,891.29 6,746.79 3,576.09 -1,157.07 2,237,138.82 208,786.96 0.37 3,758.61 MWD+SC+sag(2) 8.038.62 6.31 356.88 6,953.01 6,808.51 3,583.17 -1,157.30 2,237,145.91 208,786.91 0.92 3,765.43 MWD+SC+sag(2) 8,100.57 6.34 356.45 7,014.58 6,870.08 3,589.99 -1,157.69 2,237,152.73 208,786.68 0.09 3,772.03 MWD+SC+sag(2) 8,162.83 6.68 356.95 7,076.44 6,931.94 3,597.03 -11158.10 2,237,159.78 208,786.44 0.55 3.778.87 MWD+SC+sag(2) 8,226.07 6.66 355.75 7,139.25 6,994.75 3,604.36 -1,158.57 2,237,157.12 208,786.15 0.22 3,785.99 MWD+SC+sag(2) 8,285.79 6.24 351.15 71198.60 7,054.10 3,611.02 -1,159.32 2,237,173.80 208,785.55 1.11 3,792.55 MWD+SC+sag(2) 6212017 5:26:09PM Page 5 COMPASS 5000.1 Build 81 Company: Hilcorp Alaska, LLC Project: Ninilchik Unit Site: Kalotsa Well: Kalotsa 3 Wellbore: Kalotsa 3 Design: Kalotsa 3 Halliburton Definitive Survey Report Local Cc -ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Kalotsa 3 Kalotsa 3 W P05 @ 144.50usft Kalotsa3 WP05 @ 144.50usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,350.81 5.54 348.13 7,263.27 7,118.77 3,617.59 -1,160.51 2,237.180.39 208,784.52 1.18 3,799.17 MWD+SC+sag (2) 8,413.63 6.08 349.47 7,325.77 7,181.27 3,623.83 -1,161.74 2,237,186.65 208,783.44 0.89 3,805.49 MWD+SC+Sag(2) 8,475.68 7.01 354.25 7,387.41 7,242.91 3,630.62 -1,162.72 2,237,193.67 208,782.63 1.74 3,812.45 MWD+SC+sag(2) 8,538.74 7.04 355.25 7,450.00 7,305.50 3,638.50 -1,163.43 2,237,201.37 208,782.11 0.20 3,819.98 MWD+SC+sag(2) 8,600.45 5.68 350.42 7,511.33 7,366.63 3,645.28 -1,164.25 2,237,208.17 208,761.45 2.37 3.825.69 MWD+SC+sag(2) 8,663.77 6.03 353.10 7.574.32 7,42982 3,651.68 -1,165.17 2,237,214.58 208,780.68 0.70 3,833.05 MWD+SC+sag(2) 8,724.96 5.91 350.91 7,635.18 7,490.68 3,657.98 .1,166.05 2,237,220.90 208,779.95 0.42 3,839.32 MWD+SC+sag(2) 8,78189 6.09 349.92 7,697.76 7,553.26 3,664.46 -1,167.15 2,237,227.41 208,779.01 0.33 3.845.83 MWD+SC+sag(2) 8,849.22 5.24 346.58 7,756.79 7,614.29 3,670.39 -1,168.37 2,237,233.36 208,777.94 1.49 3,851.85 MWD+SC+sag (2) 8,911.25 4.99 343.88 7,820.58 7,676.08 3,675.74 -1,169.78 2,237,238.74 208.776.66 0.56 3,857.37 MWD+SC+sag(2) 8,974.93 5.11 342.08 7,884.01 7,739.51 3,681.10 -1,171.42 2,237,244.14 208,775.15 0.31 3,862.97 MWD+SC+sag(2) 9,035.86 4.92 340.59 7.945.70 7,801.20 3,686.23 -1,173.15 2,237,249.31 208,773.54 0,37 3,868.39 MWD+SC+sag(2) 9,099.01 4.31) 338.41 8,007.65 7,863.15 3,690.91 -1,174.89 2,237,254.03 208,771.91 1.04 3,873.38 MWD+SC+sag(2) 9,162.33 3.96 341.64 8,070.81 7,926.31 3,695.19 -1,176.45 2,237,258.35 208,770.45 0.65 3,877.93 MWD+SC+sag(2) 9,228.73 3.58 348.05 8,137.06 7,992.56 3,699.39 -1,177.61 2,237,262.58 208,769.40 0.85 3,882.29 MWD+SC+sag(2) 9,265.00 . 3.58 348.05 8,173.26 • 8,028.76 3,701.61 -1,178.07 2,237,264.81 208,768.99 0.00 3,884.54 PROJECTED to TD Checked By: Michael Calkins Approved By: «`t°"t"°r@h'llieener<'».- Date: 6/21/17 6/21/2017 5:26:09PM Page 6 COMPASS 5000.1 Build 61 Lease & Well No. County Hilcorp Energy Company CASING & CEMENTING REPORT NINU Kalotsa 3 Date Run 9 -Jun -17 State Alaska Supv. C. Montague / R. Wall CASING RECORD Surface �' TD 1,423.00 Shoe Depth: 1,419.65 PBTD: 1,336.05 No. its. Delivered 49 No. its. Run 35 No. its. Returned 14 Ftg. Delivered 2,000.00 Ftg. Run 1,391.00 Ftg. Returned 609.00 Length Measurements W/O Threads Ftg. Cut Jt. Fig. Balance RKB 18.00 RKB to BHF RKB to CHF RKB to THF Csg Wt. On Hook: 50,000 Csg Wt. On Slips: 38,000 Rotate Csg Yes X No Fluid Description: spud Liner hanger Info (Make/Model): Liner hanger test pressure: Centralizer Placement: Type Float Collar: Antelope No. Hrs to Run: 7 Type of Shoe: Antelope Casing Crew: Weatherford Recip Csg X Yes No 45 Ft. Min. 9.2 PPG CEMENTING REPORT Shoe @ 1419.65 FC @ 1,336.05 lush (Spacer) .. Clean Spacer III Density (ppg) 10 J Slurry Class A sity (ppg) 12 Volume pumped (BBLs) 84 Slurry .. Class G :y (ppg) _ =lush (Spacer) water 15.4 Volume pumped (BBLs) 36 Liner top Packer?: _Yes No Floats Held X Yes No Top of Liner #WA Volume pumped (BBLs) 31.3 Sacks: 200 Yield: 2.43 Mixing / Pumping Rate (bpm): 4 Sacks: 155 Yield: 1.23 Mixing / Pumping Rate (bpm): Density (ppg) 8.34 Rate (bpm): 4 Volume: 10 Mud Density (ppg) 9.2 Rate (bpm): Casing (Or Liner) Detail 60.5/61 (psi): 440 Pump used for disp: Setting Depths its. Component Size Wt. Gmde THD Make Length Bottom Top Float Shoe 85/8 40.0 L-80 BTC Antelope 1.45 1,419.65 1,418.20 2 Casing 75/8 29.7 L-80 BTC USS 80.86 1,418.20 1,337.34 Float collar 85/8 29.7 L-80 BTC Antelope 1.29 1,337 'AA 1,336.05 33 Collar 75/8 29.7 L-80 BTC U55 1,303.42 1,336.05 25.63 hanger & pup 103/4 45.0 L-80 BTC Cactus 4.30 25.63 21.33 Csg Wt. On Hook: 50,000 Csg Wt. On Slips: 38,000 Rotate Csg Yes X No Fluid Description: spud Liner hanger Info (Make/Model): Liner hanger test pressure: Centralizer Placement: Type Float Collar: Antelope No. Hrs to Run: 7 Type of Shoe: Antelope Casing Crew: Weatherford Recip Csg X Yes No 45 Ft. Min. 9.2 PPG CEMENTING REPORT Shoe @ 1419.65 FC @ 1,336.05 lush (Spacer) .. Clean Spacer III Density (ppg) 10 J Slurry Class A sity (ppg) 12 Volume pumped (BBLs) 84 Slurry .. Class G :y (ppg) _ =lush (Spacer) water 15.4 Volume pumped (BBLs) 36 Liner top Packer?: _Yes No Floats Held X Yes No Top of Liner #WA Volume pumped (BBLs) 31.3 Sacks: 200 Yield: 2.43 Mixing / Pumping Rate (bpm): 4 Sacks: 155 Yield: 1.23 Mixing / Pumping Rate (bpm): Density (ppg) 8.34 Rate (bpm): 4 Volume: 10 Mud Density (ppg) 9.2 Rate (bpm): 5 Volume (actual / calculated): 60.5/61 (psi): 440 Pump used for disp: Halliburton Bump Plug? X Yes No Bump press 110( ig Rotated? _Yes X No Reciprocated? X Yes —No % Returns during job 100 ant returns to surface? X Yes —No Spacer returns? X Yes Vol to Surf: 30 ` MT ant In Place At: 22:45 Date: 6/9/2017 —No Estimated TOC: 22 od Used To Determine TOC: returns Post Job Calculations: Calculated Cmt Vol @ 0% excess: 75.4 Total Volume cmt Pumped: 120 Cmt returned to surface: 30 Calculated cement left in wellbore: 90 ✓ OH volume Calculated: 49 OH volume actual: 67 Actual % Washout: 36 www.weliez.net WellEz Information Management LLC ver 102716bf Lease & Well No. County Hilcorp Energy Company CASING 8: CEMENTING REPORT NINU Kalotsa 3 Date Run 25 -Jun -17 State Alaska Supv. R. Pederson / A. Dom CASING RECORD Production � TD 9,265.00 Shoe Depth: 9,254.34 PBTD: No. Jts. Delivered No. As. Run 222 Ftg. Delivered Length Measurements W/O Threads Ftg. Cut Jt. RKB 18.00 IRKS to BHF Fig. Run 9,235.22 Fig. Balance RKBto CHF 9,169.00 No. Jts. Returned Fig. Returned RKB to THF Csg Wt. On Hook: Type Float Collar: Antelope No. Hrs to Run: Csg Wt. On Slips: Type of Shoe: Antelope Bullnose Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg _ Yes X No Ft. Min. 9.8 PPG Fluid Description: 6%KCL Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: 150 total Hvdroforms. 0 per joint #1 - #105, 1 every other ioint #107 - #186) CEMENTING REPORT Shoe @ 9254 FC @ 9,169.00 Top of Liner lush (Spacer) Tuned Spacer III Density (ppg) 12 Volume pumped (BBLs) I Slurry ,. Type 1 -II Sacks: 675 Yield: sity (ppg) 12.5 Volume pumped (BBLs) 240 Mixing / Pumping Rate (bpm): Slurry ,. Class G Sacks: 160 Yield: sity (ppg) 15.3 Volume pumped (BBLs) 32 Mixing / Pumping Rate (bpm): I Flush (Spacer) Density (ppg) Rate (bpm): Volume: 6% KCL Density (ppg) 8.6 Rate (bpm): 6 Volume (actual / calculated): Casing (Or Liner) Detail (psi): 2300 Pump used for disp: Halliburton Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Date: 6/26/2017 Shoe 5 od Used To Determine TOC: Spacer Returns (3 bbls) TXP Antelope 1.40 9,254.34 9,252.94 2 Casing 41/2 12.6 L-80 TXP Tenaris 82.40 9,252.94 9,170.54 Float Collar 5 TXP Antelope 1.27 9,170.54 9,169.27 192 Casing 41/2 12.6 L-80 TXP Tenaris 7,873.54 9,169.27 1,295.73 Pup 1 41/2 12.6 L-80 TXP Tenaris 8.93 1,295.7 1,286.80 Swell Packer) 6 12.6 TXP Baker 6.04 ,286.80 1,280.76 41/2 12.6 L-80 TXP Tenaris 14.66 .76 1,266.10 30 Casing 41/2 12.6 L-80 TXP Tenaris 1,243.45 1,266.10 22.65 Pup Jt 41/2 12.6 L-80 TXP Tenaris 2.58 22.65 20.07 Hanger 7 TXP Cactus 0.95 20.87 19.12 Csg Wt. On Hook: Type Float Collar: Antelope No. Hrs to Run: Csg Wt. On Slips: Type of Shoe: Antelope Bullnose Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg _ Yes X No Ft. Min. 9.8 PPG Fluid Description: 6%KCL Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: 150 total Hvdroforms. 0 per joint #1 - #105, 1 every other ioint #107 - #186) CEMENTING REPORT Shoe @ 9254 FC @ 9,169.00 Top of Liner lush (Spacer) Tuned Spacer III Density (ppg) 12 Volume pumped (BBLs) I Slurry ,. Type 1 -II Sacks: 675 Yield: sity (ppg) 12.5 Volume pumped (BBLs) 240 Mixing / Pumping Rate (bpm): Slurry ,. Class G Sacks: 160 Yield: sity (ppg) 15.3 Volume pumped (BBLs) 32 Mixing / Pumping Rate (bpm): I Flush (Spacer) Density (ppg) Rate (bpm): Volume: 6% KCL Density (ppg) 8.6 Rate (bpm): 6 Volume (actual / calculated): 139, (psi): 2300 Pump used for disp: Halliburton Bump Plug? X Yes No Bump press lg Rotated? _Yes X No Reciprocated? _Yes X No % Returns during job 80 ant returns to surface? _Yes X No Spacer returns? X Yes _ No Vol to Surf: 442 ant In Place At: 13:06 Date: 6/26/2017 Estimated TOC: 1,077 od Used To Determine TOC: Spacer Returns (3 bbls) 31 : Not r nail f 7,54 " .5Aa- Calculated Cmt Vol @ 0% excess: 232.5 Total Volume cmt Pumped: 275.8 Cmt returned to surface: 0 Calculated cement left in wellbore: 275.8 OH volume Calculated: 196 OH volume actual: Actual % Washout: www.weliez.net WellEz Information Management LLC ver 102716bf 4 4.5 THE STATE °fALASKA GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 3 Permit to Drill Number: 217-028 Sundry Number: 317-440 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 www.cogcc.aloska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Per 20 AAC 25.215(b) commingling of production from two or more pools is prohibited without an order from the Commission. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair 1� DATED this Z2 day of September, 2017. RBDMS ��/ lip , -j 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® SEP 182017 voGCC �T 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: Hilcorp Alaska, LLC Exploratory ❑ Development ❑v Stratigraphic ❑ Service ❑ 217-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20661-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701A Will planned perforations require a spacing exception? Yes ❑ No Kalotsa 3' 9. Property Designation (Lease Number): 10. Field/Pool(s): C061505 SHL / ADL359242 / ADL384372 TPH/BHL Ninilchik Field - Belugarryonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,265' 6,724' 9,169' 6,626' 2,607 9,012' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,318' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2" 9,252' 8,160' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A WA Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Pkr; N/A 1,280' MD/1,203' TVD; N/A 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: October 6, 2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(nriZhilcoro.com Contact Phone: 777-8420 Authorized Signature: Date: )f If COMMISSI N USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 �7-yea Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes F1 No `' 7 2011 Spacing Exception Required? Yes ❑ No Subsequent Form Required: p �-4/� IJ RBDMS Vv �'--'� G APPROVED BY lLZ l Approved by: COMMISSIONER THE COMMISSION Date: n t t-4 1'7,l /• / % ^yi Submit Form and i v Form 70-x03 Revised 412017 O RA[o`4 Ni PL valid for2/,-,nths from the date of approval. /Q«achments' Duplicate U ruroom Alaska, ur, Well Prognosis Well: Kalotsa #3 Date:9/18/2017 Well Name: Kalotsa #3 API Number: 50-133-20661-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: October 6th, 2017 Rig: E -Line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Do not commingle Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: 1710632C Perfs Maximum Expected BHP: Max. Potential Surface Pressure Brief Well Summary — 3,398 psi @ 7,902' TVD — 2,607 psi @ 7,902' TVD (Based on normal gradient of 0.43 psi/ft and the lowest proposed perforation) (Based on expected BHP and gas gradient to surface (0.10psi/ft) Kalotsa #3 is a grass roots development well targeting gas sands in the Tyonek formation. This new well reached TD on 6/21/17 and completed 6/27/17. The Tyonek T-147 sand was perforated in July 2017 and found % non-productive. The offset well Kalotsa #4 perforated the T-146 Sand and found it productive and this sundry is to perforate the T-146 in Kalotsa #3 and test, prior to moving up into the Tyonek Sands that are in the pool. Hilcorp understands that this T-146 Sand cannot b_ a comi_gled with the other shallower Tyonek Sands as they are deeper than existing pool Rules as defined in the Ninilchik Beluga/Tyonek Gas Pool, which has a hearing scheduled for October 24th. Notes Regarding Wellbore Condition • T-147 Sand is plugged back and no open perfs currently in wellbore. E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. • If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation, estimated pert pressure — 2,600psi. 2. Perforate the Tyonek T-146 sand with 2-7/8" 6 SPF 60 deg phased pert guns (up to 12 SPF with 2 perf runs) Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Do not commingle Tyonek T346 ±8,960' 18,995' ±7,869' ±7,902' 35 zone with any other Perfs 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 pert 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. Well Prognosis Well: Kalotsa #3 ua<aru ,uaeka' LD Date: 9/18/2017 f. Rule 2 of Conservation Order 701A defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. The proposed set of perfs (8,960'-8,995') in the Tyonek T-146 sand are fall below the defined base of the Ninilchik Beluga/Tyonek Gas Pool (9,600' as correlated in the Paxton #1 well), as submitted in Sundry # 317-310. Hilcorp proposes to shoot this zone individually (no commingling) and test for production. If this zone proves non-productive, the interval will be plugged back and perforating the sands list in Sundry 317-310 will be shot. 3. POOH. 4. RD a -line. 5. Turn well over to production. (Test SSV with -in 5 days of stable production on well —notify AOGCC 24hrs before testing) Attachments: Actual and Proposed Well Schematics Map showing spacing between Kalotsa #3 and #4 RKB to GL=19.1' 16" u u 7-5/8" 6 -3/4 - Hole k RA@3,987' RA @ 5,438' RA @ 6,474' ♦ a 1" o. RA @ 7,470' ..o L . 0/ 9,007 )9/ X9/10/17 -- 2 4-1/2" PBTD = 9,169'/ PBTVD = 6,626' TD = 9,265'/ TVD = 6,724' CURRENT SCHEMATIC CASING DETAIL Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 Size Type Wt Grade Conn. ID Top Btm 16" Conductor — Driven to Set Depth 84 X-56 Weld 15.01" Surt 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 UP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID OD Item 1 1,280' 3.958" 6.875" Swell Packer 2 9,012' (Np) 3.958" CIBP w/ 5' of cement 9/10/17 OPEN HOLE / CEMENT DETAIL PERFORATION DETAIL Sands 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Btm (MD) Class G tail. 100% returns throughout, 30 bbls to surface. 4-112' 6-3/4" hole. 240 BBL (675 5x)12.5 Type 1 -II cement, followed with 32 BBL (1605x) of Date Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) FT Date Status (Np) T147 ±9,022' 1 ±9,033' 1 ±7,931' 1 ±7942' 11 07/27/17 Isolated Updated by CAH 09-18-17 flilaorp Alaska, l.LC RKB to GL= 19.1' 16" 7-5/8" 6-3/4" Hole RA @ 3,987' ) RA @ 5,438' RA @ 6,474' RA @ 7,470' TOC @ 9,007' 09/10/17 4-1/2" PROPOSED SCHEMATIC 2 PBTD = 9,169'/ PBND = -8,077' TD = 9,265'/ ND =-8,173' CASING DETAIL Ninilchik Unit Kalotsa #3 PTD: 217-028 API: 50-133-20661-00 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 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth ID CI Item 1 1,280' 3.958" 6.875" Swell Packer 2 9,012' ±3,958' 3.958" CIBP w/ 5' cement 09/10/17 OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Btm (MD) Class G tail. 100% returns throughout, 30 bbis to surface. 4-112- 6-3/4" hole. 240 BBL (675 sx)12,5 Type 1 -II cement, followed with 32 BBL (160sx) of Date Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (ND) Btrn (TVD) FT Date Status T4 ±4,630' ±4,642' ±3,948' ±3,958' 12 TBD Sundry317-310 T5C ±4,787 ±4,799' ±4,079' ±4,090' 12 TBD Sundry 317-310 T6B ±4,980' ±4,994' ±4,243' ±4,254' 14 TBD Sundry 317-310 T8 ±5,058' ±5,106' ±4,308' ±4,348' 48 TBD Sundry 317-310 TSO ±5,181' ±5,193' ±4,412' ±4,422' 12 TBD Sundry 317-310 T31 ±5,354' ±5,370' ±4557' ±4,570' 16 TBD Sundry 317-310 T12 +5,519' ±5,542' ±4,692' ±4710' 23 TBD Sundry 317-310 ±5,555' ±5,642' ±4,721' ±4,792' 87 TBD Sundry 317-310 T37 ±6,179' ±6,193' ±5,240' ±5,252' 14 TBD Sundry 317-310 ±6,207' ±6,225' ±5,263' ±5,278' 18 TBD Sundry 317-310 T17A ±6,249' ±6,283' ±5,298' ±5,327' 34 TBD Sundry 317-310 T43 ±6,888' ±6,900' ±5,845' ±5,856' 12 TBD Sundry 317-310 T53 ±7,426' ±7,448' ±6,349' ±6,370' 22 TBD Sundry 317-310 T80 ±7,88V ±7,890' ±6,800' ±605' 5 TBD Sundry 317-310 T87 ±8,007' ±8,023' ±6,922' ±6,937' 16 TBD Sundry 317-310 T115 ±8,449' ±8,516' ±7,361' ±7,427' 67 TBD Sundry 317-310 T142 ±8,767' ±8,777• ±7,677' ±7,687' 10 TBD Sundry 317-310 T146 ±8,960' ±8,995' ±7,869' ±7,902' 35 TBD Proposed T147 ±9,022' ±9,033' ±7,931' ±7,942' 11 07/27/17 Isolated Updated by CAH 09-17-17 2 KALOTSA3 T146 [JFD] : -7,66 3997 Between wells - at [he same formation KALOTSA 4 1500' Radius for both T146 [JFD] : -7,590 Kalotsa 3 and Kalotsa 4 D Hilcwrp Alaska Kalotsa Pad TWOD'sWw POSTED W ELLOATA IYIMf nY(nOl Yfillvtl 11 WELL SVMBGLS wY weu Oy S0.N I CM R,fIM FEET 21 7028 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive 2 8 1 0 4 C Anchorage, AK 99503 Tele: 907 777-83 RECEIVED Fax: 907777-85010 E-mail: snolan@hilcorp.com SEP 19 2017 AOGCC DATA LOGGED DATE 09/18/2017 9istizoi'1 M.K.eENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant II 333 W 7th Ave Ste 100 Anchorage, AK 99501 Core Data CDl: . Thin-Section—SOX 9/18/20178:35 AM File folder F,{J Hilcorp Kalotsa 3 HH -95472 Rotary Core Dat... 9/18/2017 8:33 AM Microsoft Excel W or... 37 KB Hillcorp Kalotsa 3 HH -95472 CEC Data - B-16... 9/18/2017 8:33 AM Microsoft Excel Wor... 27 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: y1 ate: DATE 07/18/2017 Seth Nolan GeoTech RECEIVED JUL 19 2017 AOGCC 21 7028 Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED 1 i X1201'1 M. K. BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 Elog Prints and Digital data Prints 28420 28423 28421 28424 28422 28425 28446 2Y5" ROP-DGR-EWR- CTN-ALD MD 5" FORMATION LOG MD/TVD 2"/5" DGR-EWR-CTN- ALD TVD 2" FORMATION LOG MD/TVD ECS -GR 2" LWD COMBO LOG MD/TVD HNGS-GR 2" GAS RATIO LOG MD/TVD PNX-GR 2" DRILLING DYNAMICS MD/TVD PNX-PBMS FINAL WELL REPORT CBL-VDL-GR-CCL CDl: Mudlogs . Daily Reports 7/17/2017 3:51 PM File folder . DML Data 7/17/2017 3:52 PM File folder . Final Well Report 7/17/2017 3:52 PM File folder . LAS Data 7/17/2017 3:52 PM File folder . Log PDFs 7/17/2017 3:54 PM File folder . Log TIFFS 7/17/2017 3:55 PM File folder . Show Reports 7/17/2017 3:50 PM File folder CD2: LWD . _Log Viewers 7/6/2017 8:52 AM File folder . CGM 7/6/2017 8:53 AM File folder . EMF 7/6/2017 8:53 AM File folder . LAS 7/6/2017 8:53 AM File folder . PDF 7/7/2017 8:36 PM File folder . TIFF 7/6/2017 8:54 AM File folder CD3: PNX 06/23/2017 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: „ _ , I Date: DLIS Data LAS Data Log CD4: PNX 07/09/2017 DLIS Data LAS Data Log CDS: ECS DLIS Data LAS Data Log CD6: XPT DLIS Data LAS Data Log CD7: CBL DLIS Data LAS Data Log Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com 7JS12017 8:05 AM File folder 7/7/2017 12:52 PM File folder 7/5/2017 8:05 AM File folder 7118J2017 7:59 AM File folder 7/18/2017 8:09 AM File folder 7/18/20178:09 AM File folder 715/2017 7:57 AM File folder 7/5/2017 7:58 AM File folder 7/5/2017 7:58 AM File folder 7/5/2017 7:54 AM File folder 7/512017 7:55 AM File folder 71512017 7:55 AM File folder 7/18/20178:14AM File folder 7/18/2017 8:15 AM File folder 7/18/2017 8:15 AM File folder Please include current contact information if different from above. 28423 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: ^ _ ,, I Date: ffil.,q Alwk, LII: DATE 07/18/17 L _ -a Nolan Hilcorp Alaska, LL, GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: AOGCC Meredith Guhl 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 WELL SAMPLE INTERVAL KALOTSA 3 1412-2700 KALOTSA 3 2700 —3900 KALOTSA 3 3900 —5220 KALOTSA 3 5220 —6600 KALOTSA 3 6600 —7980 KALOTSA 3 7980-9264 Please include current contact information if different from above. RECEIVED JUL 19 2017 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Ler 6y: Date: '4I 2 I 1 I THE STATE GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 3 Permit to Drill Number: 217-028 Sundry Number: 317-310 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W Wvs.aogcc.alaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. kl DATED this( C day of July, 2017. Sincerely, dm-----� Hollis S. French Chair RBDMS MUL 1 1 20'17 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on Aar 99 oan RECEIVE® OTS –7/� 0 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ , Operations shutdown ❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Atter Casing ❑ Other: CT N2 Lift ❑Q ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q � Stratigraphic ❑ Service ❑ 217-028 . 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20661-00' 7. If perforating: LO.74bl4 18. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? z4BA— Will planned perforations require a spacing exception? Yes ❑ No ❑Q Kalotsa 3 9. Property Designation (Lease Number): 10. Field/Pocl(s): C061505 SHL / ADL359242 / ADL384372 TPH/BHL Ninilchik Field - Beluga/Tyonek Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,265' 6,724' 9,169' 6,626 2,621 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,960psi 1,410psi Surface 1,418' 7-5/8" 1,418' 1,318' 6,890psi 4,790psi Intermediate Production 9,252' 4-1/2^ 9,252' 8,160' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Pkr; N/A 1,280' MD/1,203' TVD; N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Strati ra hic g p ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 21, 2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS Q ' WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkr911191@12lcoro com Contact Phone: 777-8420 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test7El— Mechanical Integrity Test 01 Location Clearance A Other: CDO Pry Z F–D –1 G� 1 MkT- 1a -'M 2Sco PSA Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBEINIS U �, JUL 1 1 2617 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY I I Approved by: COMMISSIONER THE COMMISSION Date: t t Vr) 1^ O R4G4 NAL � ro ,ItOf t, Submit Form and 07 Form 10-403 Revised 4/2017 ' ` i valid for 12 months from the date of �r ( P approval. Attachments in Duplicate j R lhl.m Alaska, LL, Well Prognosis Well: Kalotsa #3 Date: 7/7/2017 Well Name: Kalotsa #3 API Number: 50-133-20661-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: July 21st, 2017 Rig: Coil Unit Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-028 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: 171O632C Maximum Expected BHP: Max. Potential Surface Pressure Brief Well Summary 3,415 psi @ 7,942' TVD - 2,621 psi @ 7,942' TVD (Based on normal gradient of 0.43 psi/ft and the lowest proposed perforation) (Based on expected BHP and gas gradient to surface (0.10psi/ft) Kalotsa #3 is a grass roots development well targeting gas sands in the Tyonek formation. This new well reached TD on 6/21/17 and completed 6/27/17. The purpose of this work/sundry is to evaluate cement, jet the well dry with coil tubing, and perforate. Notes Regarding Wellbore Condition • Well is filled with 137 bbls 6% KCI. -X- t $L. • Slickline tag and make gauge ring run prior to starting work. • E -line will complete CBL prior to starting sundry work. Electronic copy of CBL to be sent to AOGCC when Mim completed. -p Legs • An MIT -IA (7-5/8" x 4-1/2") will be performed to 2.500 psis for 30 minutes using the coiled tubing pumps prior to beginning of sundry work. <_7 C*AA2c M %-C ., sni ,o Gw^RT Safety Concerns Zo ND 6&— • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people Ao n could enter. • Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) • Ensure all crews are aware of stop job authority Coiled Tubing Procedure (start of Sundry work) VII 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. If slickline or eline tags cement shallower than 9,100'. Follow steps 2-6 & 9-11. 2. MU Mill and Motor BHA. 3. RIH and mill cement and cleanout to 9,100' MD. 4. Circulate hole clean with 2 bottoms up, ensure any rubber or cement is free from the hole. 5. RU N2 pumping unit. 6. Drop ball and come online with N2 and jet well dry. • Estimated volume of displaced 6% KCI is 137 bbls. If slickline or eline tags cement deeper than 9,100'. Proceed with steps 7-11. U Mmrp Alaska, M Well Prognosis Well: Kalotsa #3 Date: 7/712017 7. RIH w/ coiled tubing and jet nozzle BHA and tag PBTD. 8. PU 5ft and displace well fluids with Nitrogen. • Estimated volume of displaced 6% KCI is 137 bbl. 9. Once well is dry, verify desired surface pressure to leave on well with Operations Engineer. 10. POOH w/ coil. LD BHA. 11. RD Coiled Tubing. E -Line Procedure 12. MIRU a -line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. Note that the well is pressurized with nitrogen. • If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 13. Perforate the following Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns (up to 12 SPF with 2 perf runs) Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Tyonek T4 ±4,630' ±4,642' ±3,948' ±3,958' 12 Tyonek T5C ±4,787' ±4,799' ±4,079' ±4,090' 12 Tyonek T6B ±4,980' ±4,994' ±4,243' ±4,254' 14 Tyonek T8 ±5,058' ±5,106' ±4,308' ±4,348' 48 Tyonek T10 ±5,181' ±5,193' ±4,412' ±4,422' 12 Tyonek T11 ±5,354' ±5,370' ±4,557' ±4,570' 16 Tyonek T12 ±5,519' ±5,542' ±41692' ±4,710' 23 Tyonek T12 ±5,555' ±5,642' ±4,721' ±4,792' 87 Tyonek T17 ±6,179' ±6,193' ±5,240' ±5,252' 14 Tyonek T17 ±6,207' ±6,225' ±5,263' ±5,278' 18 Tyonek T17A ±6,249' ±6,283' ±5,298' ±5,327' 34 Tyonek T43 ±6,888' ±6,900' ±5,845' ±5,856' 12 Tyonek T53 ±7,426' ±7,448' ±6,349' ±6,370' 22 Tyonek T80 ±7,885' ±7,890' ±6,800' ±6,805' 5 Tyonek T87 ±8,007' ±8,023' ±6,922' ±6,937' 16 Tyonek T115 ±8,449' ±8,516' ±7,361' ±7,427' 67 Tyonek T142 ±8,767' ±8,777' ±7,677' ±7,687' 10 Tyonek T147 ±9,022' ±9,033' ±7,931' ±7,942' 11 Do not commingle zone with any above 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 pert 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. f. Rule 2 of Conservation Order 701A defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. The proposed bottom set of perfs (9,022'-9,033) in the Tyonek T-147 sand are fairbelow the defined base of the Ninilchik Beluga/Tyonek Gas Pool (9,600' as correlated in the Paxton #1 well), see attached log. H lik.n, Alaska. LL, Well Prognosis Well: Kalotsa #3 Date: 7/7/2017 Hilcorp proposes to shoot this zone individually (no commingling) and test for production. If this zone proves productive, Hilcorp requests the AOGCC take administrative action to modify Rule 2 of CO 701A to vertically expand the defined pool to the newly proven productive interval. If this zone proves non-productive, the interval will be plugged back before any other zones are perforated. A total of 9 wells have been drilled into or below the T-146 in this Pax -SD structure, but has not been perforated or tested in any of those wells • C t �c � pb , e zj;e c.tt_/ W 7Cie j( The rest of the perforations in table above are fall within the defined Ninilchik BelugalTyonek Gas Pool, as currently defined. 7 14. POOH. 15. RD e -line. 7 16. Turn well over to production. (Test SSV with -in 5 days of stable production on well —notify AOGCC 24hrs before testing) E -line Procedure (Contingency): 1. If any zone produces sand and/or water or needs isolated 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 3. RIH and set 4-1/2" CIBP at depth above zone. Or 4. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Ninilchik Kalotsa #3 Correlation Log showing the 9,600' marker 2. Actual and Proposed Well Schematics 3. Coil BOPE Schematic 2-3/8" coil (Comb! BOPS) 4. CT Flow Diagrams (Forward and Reverse Jetting) 5. Wellhead Diagram 6. Blank RWO Change Form 7. Standard Well Procedure— N2 Operations Ninilchik Unit 11 CURRENT SCHEMATIC pTDt217-028 I1iMorp Alxska, LLC API: 50-133-20661-00 RKB to GL= 19.1' 16 1 PBTD = 9,169' / PBTVD = 6,626' TD = 9,265'/ TVD = 6,724' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor — Driven to Set Depth 84 '1 Weld 15.01" Surf 6 -3/4 - 7-5/8" Surf Csg Hole L-80 BTC 4' Surf 1,418' 4-1/2" Prod Csg r. RA @ 3,987' " • e TXP - w 9,252' S' .a V- RA @ 5,438' 4" os 'H 1A @ 6,474' -1 A @ 7,470' -AA PBTD = 9,169' / PBTVD = 6,626' TD = 9,265'/ TVD = 6,724' 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 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth 1 ID OD Item 1 1,280' 1 3.958" L6.875" 1 Swell Packer OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx) 15.4 ppg Class G tail. 100% returns throughout, 30 bbls to surface. 4-1/2" 6-3/4" hole. 240 BBL (675 5x)12.5 Type 1-11 cement, followed with 32 BBL (160sx) of Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. Updated by CAH 07-07-17 Ninilchik Unit 11 PROPOSED SCHEMATIC PTDt217-028 HLLC API: 50-133-20661-00 ilmry AI"aka, RKB to GL= 19.1' 16" LJ;; 7 5/8' 6 -3/4 - Hole k , Type Wt Grade Conn. ID Top i 16" Conductor -Driven to Set Depth 84 �he . 15.01" Surf dM r'f Surf Csg 29.7 L-80 Z` 6.875" Surf �•A x 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' T8 ±5,058' ±5,106' ±4,308' ±4,348' 48 TBD Proposed PBTD = 9,169'/ PBTVD = 6,626' TD = 9,265'/ TVD + 6,724' 1 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 BTC 6.875" Surf 1,418' 4-1/2" Prod Csg 12.6 L-80 TXP 3.958" Surf 9,252' JEWELRY DETAIL No. Depth I ID OD Item 1 1,280' 3.958" 6.875" Swell Packer OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 84 BBL (200 sx) of 12 ppg Class A lead and 36 BBLs (155sx)15,4 ppg Btm (MD) Class G tail. 100% returns throughout, 30 bbls to surface. 4-112" 6-3/4" hole. 240 BBL (675 sx)12,5 Type 1-11 cement, followed with 32 BBL (160sx) of Date Class G tail. Lost 63 bbls during job, 3 bbls of spacer returned to surface. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm ( FT Date Status T4 ±4,630' ±4,642' ±3,948' ±3,958' 12 TBD Proposed TSC ±4,787' ±4,799 ±4,079' ±4,090' 12 TBD Proposed 1`613 ±4,980' ±4,994' ±4,243' ±4,254' 14 TBD Proposed T8 ±5,058' ±5,106' ±4,308' ±4,348' 48 TBD Proposed T10 ±5,181' ±5,193' ±4,412' ±4,422 12 TBD Proposed T31 ±5,354' ±5,370' ±4,557' ±4,570' 16 TBD Proposed T12 ±5,519' ±5,542' ±4,692' ±4,710' 23 TBD Proposed ±5,555' ±5,642' ±4,721' ±4,792' 87 TBD Proposed ±6,179' ±6,193' ±5,240' ±5,252' 14 TBD Proposed T17 ±6,207' ±6,225' ±5,263' ±5,278' 18 TBD Proposed T17A ±6,249' ±6,283' ±5,298' ±5,327' 34 TBD Proposed T43 ±6,888' ±6,900' ±5,845' ±5,856' 12 TBD Proposed T53 ±7,426' ±7,448' ±6,349' ±6,370' 22 TBD Proposed T80 ±7,885' ±7,890' ±6,800' ±6,805' 5 TBD Proposed T87 ±8,007' ±8,023' ±6,922' ±6,937' 16 TBD Proposed T115 ±8,449' ±8,516' ±7,361' ±7,427' 67 TBD Proposed T142 ±8,767' ±8,777' ±7,677' ±7,687' 30 TBD Proposed T147 ±9,022' ±9,033' ±7,931' ±7,942' 11 TBD Proposed Updated by CAH 07-07-17 Client: Hilcorp Schlumberger Coiled Tubing Services Date: April 3ftl,2017 Drawn: Chad Barrett Pressure Category 1 BOP Configuration Revision: 0 (0-3,500 psi) Well Category: CAT 2-1/16 IOK R (a Coiled Tubing HR580 Injector Head & Gooseneck Weight =12,850 lbs 4-1/16" 10K Conventional Stripper SK C062 Lubricator 5K C062 x 4-1/16" 10K Flange 4-1/16" 10K Combi BOP Top Set aird/Shear se=dse[', Rpelslip 4.1/16" 10K Flow Cross Manuel 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Rarge MM.N 2x2Valve2:2-1116"10Kx2-1/16"10KRli e Manual 2x2 Valve3'. 2-1116' 10K x2-1/16" 10K Rarge Manuel 2x2 Valve 4'. 2'15M x 2-1116" 10K Range 4-1/16" 10K x Wellhead Adapter Flange Wellhead Coil Tubing BOP Crossover spool 4 1/16 10M X 4 1/16 5M Lubricator to injection 1.75" Tandem Stripper a oUnit Kalotsatsa 3&4 06/12/2017 Mud Cross 4 1/16 10M X 4 1/16 10M Outlet w/ 2- 2 1/16 10M full opening FMC valves .m� � _;•�� |}........ m z / 2Jk- , . Do . . §| co ! , 1 ID \ � s Qt F � � s N oV j e O r IJ] U o 0 L V N ! E6 l C y. N Z V V Z O O a` rr 0 `o � 1T n 0 ti I Co d j Y C ! i F e F � O c E O U n' cv Z O pF yptl E O ! C z i N xarerer A"*. LIA: Valve, Swab, WKM-M 41/16 SM FE, HWO, EE trim Valve, upper master, WKM-M, 41/16 5M FE, HWO, EE trim Valve, Marler, WKM-h 4 1/165M FE, HWO, EE trim Tubing head, Cactus C -291 -- APS, 13 5/8 5M x 115M, w/ 2- 21/16 SM 550 Starting head, Cactus C -29L, 13 5/8 5M x 3650 W, w/ 2-2 1/165M 550 BHTA, Otis, 41/165M FE x 6.5 Otis quick union top 16" 7 4 R" Ninilchik Unit Kalotsa #3 and #4 06/12/2017 Casing hanger, CW, 11 x4 'A DWC/C box bond x6 125" RH Aub acme box top, w/ ] 5/8 od neck, 4" type H BPV profile, OD -NL material Valva, Wing, WKMW, 31/85M FE, HWO, Valve, Wing, SSV, WKM-M, EE trim 31/85M FE, w/15"Hydraulic /\ operator O O CD CD to0 0 N M co r O N X X N 7e a c H d L o m c m co U L U �C N EE L " E c 0.9 0— E CE 3 0- TE � a) O N a 9 °) a 2.N a� d R N C N R - o m N m N R 0)= U R N L w U� 0 aoi n o a a ron > R o aci aB 0_ - co 3 aU �U aa)U O g c ¢ E U C 'p 01 O C L � 3 v a wo N O o- O N O > m 0 C Y (0 0 °3 0.2) 0 0 U ~ oU EU c0 N O n N a a VM O # � � c a � 0 Y y `o d � 4) d Q ca O a 4— a U y a d � d a o CL as i a y C�3 Q aNi R CL y s U u O C d .r ,L► a X X N 7e a c H d L o m c m co U L U �C N EE L " E c 0.9 0— E CE 3 0- TE � a) O N a 9 °) a 2.N a� d R N C N R - o m N m N R 0)= U R N L w U� 0 aoi n o a a ron > R o aci aB 0_ - co 3 aU �U aa)U O g c ¢ E U C 'p 01 O C L � 3 v a wo N O o- O N O > m 0 C Y (0 0 °3 0.2) 0 0 U ~ oU EU c0 0 n CL co Y D n d Z R � � c V > c Cloy 4) Q ca 4— 0 > N R CL X = a c Q Nto Y R >,.!E 2 M d a - M C' a v QZ m t} Z w d c c R s U 7 a a1 U O a` w R d c R CL 0 m N 0 n CL co Y D n STANDARD WELL PROCEDURE Ililcorp Alaska, LLC NITROGEN OPERATIONS 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 02 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. 12/08/2015 FINAL vl Page 1 of 1 THE STATE Alaska Oil and Gas 01A T ASK e Conservation Commission GOVERNOR BILL WALKER Monty Meyers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 333 Wesi Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 3 Hilcorp Alaska, LLC Permit to Drill Number: 217-028 Surface Location: 2262' FSL, 458' FWL, SEC. 7, TIS, R13W, SM, AK Bottomhole Location: 767' FSL, 715' FEL, SEC. 1, TIS, R14W, SM, AK Dear Mr. Meyers: Enclosed is the approved application for 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, Cathy P. Foerster Chair DATED this t7 day of March, 2017. STATE OF ALASKA Al OIL AND GAS CONSERVATION COMV PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Lj Service - Disp ❑ Ic. 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: Hiloorp Alaska, LLC Bond No. 022035244 . Kalotsa 3 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 8,900' TVD: 7,808' . Ninilchik Field Beluga/Tyonek Gas Pool 4a. Location of Well (Governments[ Section): 7. Property Designation (Lease Number): , Surface: 2262' FSL, 458' FWL, Sec 7, TIS, R13W, SM, AK • C061505 SHL'/ ADL359242 /ADL384372 TPH/BHL Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 581' FSL, 674' FEL, Sec 1, T1S, R14W, SM, AK N/A 4/3/2017 Total Depth: 9. Acres in Property: C061505 - 1615 acres • 14. Distance to Nearest Property: 767' FSL, 715' FEL, Sec 1, TIS, R14W, SM, AK ADL 359242.- 852 acres / ADL384372 3147 acres 7,084' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 144.5' 15. Distance to Nearest Well Open Surface: x- 209857 • y- 2233535 . Zone4 GL Elevation above MSL (ft): 126.5' to Same Pool: 1228' S. Dionne 3 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 34 degrees Downhole: 3514 - Surface: 2733 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling I Length MD TVD MD TVD (including stage data) Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' Driven 9-7/8" 7-5/8" 29.7# L-80 BTC 1,500' Surface Surface 1500' 1,381' Lead -506.4 ft3/Tail -182 ft3 6-3/4" 4-1/2" 12.6# L-80 DWC/CHT 8,900' Surface Surface 8,900' 7,808' 1486 ft3 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Sim Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑✓ BOP Sketch ❑✓ Drilling Program ✓ Time v. Depth Plot ❑✓ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report E] Drilling Fluid Program Q 20 AAC 25.050 requirements❑✓ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Monty Myers Email 111014@fS(O%h II COfD. COfll Printed Name Monty Myers Title Drilling Engineer Signature Phone 777-8431 Date 322017 Commission Use Only Permit to Drill Z17 API Number: >/-' / ��„'3` '�J-0(' Permit Approval See cover letter for other Number: -U D 50- cw(%pGj( Date: I requirements. ry Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ane, gas hydrates, or gas contained in shales: L_I Other: V CoQ S, / C �S 71- `t Samples req'd: Yes ❑ No Mud log req'd: Yes❑/ Nog✓ J d %� H2S measuras: Yes ❑ No� Directional svy mq'd: Yeso No C3L M l r- i lle L -r_.: a Spacing exception mq'd: Yes ❑ Nor?/ Inclination -only svy req'd: Yes❑ NoR U Post initial injection MIT req'd: Yes❑ No❑ L),vev,r4e.,- w�ue_,( ,qac Zssb3s(h)cZ) APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:3. -` f040 /®E I�INAL �i" Submit Form and For1 (Revised 11/2015) This permit is valid for 24 months from the date of appr666val (20 AAC 25.005(g)) Attachments in Duplicate 6�i 3. 7 f7 H 3/2/2017 Monty Myers Drilling Engineer Commissioner Alaska Oil & Gas Conservation Commission 333 W. 71^ Avenue Anchorage, Alaska 99501 Re: Kalotsa 3 Dear Commissioner, Attached is the application for permit to drill Kalotsa #3. Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com RECEIVED MAR 0 2 2017 io 0GCG Kalotsa #3 is an S-shaped directional grassroots development well to be drilled off of the Kalotsa pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development of the Upper Tyonek sands, as well as an area with little to no production in the Middle and Upper Beluga sands. The base plan is a directional wellbore with a kickoff point at 300' MD. Maximum hole angle will be 34 deg. and TD of the well will be 8900' TMD/ 7808' TVD, ending with 7 deg inclination left in the hole. Vertical section will be 3880 ft. Drilling operations are expected to commence approximately April 3'd 2017. The Saxon Rig # 169 will be used to drill the wellbore then run casing and cement. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC Kalotsa #3 Drilling Program Ninilchik Unit Rev 0 February 27t", 2017 U HIICOTp F� c-Pmy Contents Kalotsa #3 Drilling Procedure 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...........................................................................................................17 13.0 Cement 7-5/8" Surface Casing.....................................................................................................19 14.0 BOP NX and Test.........................................................................................................................22 15.0 Drill 6-3/4" Hole Section...............................................................................................................23 16.0 Run 4-1/2" Production Casing.....................................................................................................28 17.0 Cement 4-1/2" Production Casing...............................................................................................31 18.0 RDMO............................................................................................................................................33 19.0 BOP Schematic..............................................................................................................................34 20.0 Wellhead Schematic......................................................................................................................35 21.0 Days Vs Depth...............................................................................................................................36 22.0 Geo-Prog........................................................................................................................................37 23.0 Anticipated Drilling Hazards.......................................................................................................38 24.0 Saxon Rig 169 Layout...................................................................................................................40 25.0 FIT Procedure...............................................................................................................................41 26.0 Choke Manifold Schematic..........................................................................................................42 27.0 Casing Design Information...........................................................................................................43 28.0 6-3/4" Hole Section MASP............................................................................................................44 29.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................45 30.0 Surface Plat (NAD 27)...................................................................................................................46 31.0 Directional Plan(wp05)................................................................................................................47 B Hilcorp Eww Hwy 1.0 Well Summary Kalotsa #3 Drilling Procedure Rev 0 Well Kalotsa #3 Pad & Old Well Designation Kalotsa #3 is a grass roots well on Kalotsa Pad Planned Completion Type 4-1/2" Production tubing Target Reservoir(s) Belu a/T onek Planned Well TD, MD / TVD 8,900 MD / 7,808' TVD PBTD, MD / TVD 8,800' MD / 7,709' TVD Surface Location (Governmental) 2262' FSL, 458' FWL, Sec 7, TI S, R13 W, SM, AK Surface Location (NAD 27) X=209857.66, Y=2233535.94 Surface Location AD 83) Top of Productive Horizon (Governmental) 581' FSL, 674' FEL, Sec 1, TIS, R14W, SM, AK TPH Location NAD 27) X-208813.60, Y=2237075.26 TPH Location (NAD 83) BHL Governmental 767' FSL, 715' FEL, Sec 1, TIS, R14W, SM, AK BHL (NAD 27) X=208777.43, Y=2237262.62 BHL (NAD 83) AFE Number 1711067D AFE Drilling Days 4 MOB, 18 DRLG AFE Completion Days AFE Drilling Amount $3,143,072 AFE Completion Amount $400,000 Maximum Anticipated Pressure (Surface) 2733 psi Maximum Anticipated Pressure (Downhole/Reservoir) 3514 psi Work String 4-1/2" 16.6# S-135 CDS-40 (Saxon Owned String) RKB — GL 144.5'(126.5 + 18) Ground Elevation 126.5' BOP Equipment 11" 5M Townsend Type 90 Annular BOP 11" 5M Townsend Type 82 Double Ram 11" 5M Townsend Tye 82 Single Ram Page 2 Version 0 March, 2017 Kalotsa #3 ff Drilling Procedure Rev 0 Hileorp E� comymy 2.0 Management of Change Information H Hilcorp Alaska, LLC F E 9 C- p ir, Changes to Approved Permit to Drill Date: March 01, 2017 Subject: Changes to Approved Permit to Drill for Kalotsa #3 File #: Kalotsa #3 Drilling Program Any modifications to Kalotsa #3 Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Approval: Drilling Manager Date Prepared: Monty M Myers Drilling Engineer Date Page 3 Version 0 March, 2017 U Hilc!TE� , 3.0 Tubular Program: Kalotsa #3 Drilling Procedure Rev 0 Hole Cond OD(in) 16" ID (in) 15.01" Deift 14.822 Conn 17" Wt 84 Grade J-55 Conn .,,....., Weld Burst : `: _41sl 2980 Collapse 1410 Tension (k -lbs) - 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 4790 683 6-3/4" 4-1/2" 3.958" 3.833" 5.0" 12.6 L-80 DWC/C HT 8430 7500 288 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID in TJ OD in(ft/ft) " G Conn Burst (psi) Collapse T st 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 4 Version 0 March, 2017 n �11Cc�0� 5.0 Internal Reporting Requirements Kalotsa #3 Drilling Procedure Rev 0 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • 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. • Ensure time entry adds up to 24 hours total. • 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 • Submit a short operations update each work day to pmazzolini@bilcorp.com, mmyersa_hilcorp.com and cdingerna hilcorp.com 5.3 Intranet Home Page Morning Update • 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 • 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! I I I 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: 0:907-777-8477 C:907-350-9439 • Notify Drlg Manager 1. Paul Mazzolini: O: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers@hilcorp.com and cdinizer@hilegM.com 5.6 Casing and Curt report • Send casing and cement report for each string of casing to mmyers@hilcoEp.com and cdinger@hilcorp.com Page 5 Version 0 March, 2017 6.0 Planned Wellbore Schematic -mw PROPOSED 16" 6-3 4" Hole 4-112" PBTD=8,800' /PBT\D-7,709' TD =8,900' / TM -D - 7,808' CASING ncrmi Kalotsa #3 Drilling Procedure Rev 0 Ninilchik Well Kalotsa 773 PTD: 000-000 API: 50-00000000-00 1 fs�f a Drilling Info Hole Section Casing MW Workstring 9-7/8" 7-5/8" 8 8 PPg 4-1/2" 6-3/4" 4-1/2" 9.2-10.5 ppg 41/2" JEWELRY DETAIL No. Depih ID OD Item 1 1 1,300' 3.958" MudWei Size Type Wt Grade Cann. 10 Top Btm ht Conductor 16" -Driven 84 %-56 Weld 15.01" Surf 120' N/A to Set Depth 7-5/8" Surf Csg 29.7 L-80 ETC 6.875" Surf 1,500' 8.8 ppg - 4-1/2" Prod Csg 12.6 L-80 DHT/C 3.958" Surf 8,900' 9.5 ppg . 1 fs�f a Drilling Info Hole Section Casing MW Workstring 9-7/8" 7-5/8" 8 8 PPg 4-1/2" 6-3/4" 4-1/2" 9.2-10.5 ppg 41/2" JEWELRY DETAIL No. Depih ID OD Item 1 1 1,300' 3.958" 6.875" Baker Swell Packer Page 6 Version 0 March, 2017 n Hilcorp E� C.V�" 7.0 Drilling / Completion Summary Kalotsa #3 Drilling Procedure Rev 0 Kalotsa #3 is an S-shaped directional grassroots development well to be drilled off of the Kalotsa pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development of the Upper Tyonek sands, as well as an area with little to no production in the Middle and Upper Beluga sands. The base plan is a directional wellbore with a kick off point at 300' MD. Maximum hole angle will be 34 deg. and TD of the well will be 8900' TMD/ 7808' TVD, ending with 7 deg inclination left in the hole. Vertical section will be 3880 ft. Drilling operations are expected to commence approximately April 31d 2017. The Saxon Rig # 169 will be . used to drill the wellbore then run casing and cement. Surface casing will be run to 1,500 MD / 1,381' 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 Saxon Rig # 169 to well site 2. N/U conductor riser. (No diverter, diverter waiver requested) 3. Drill 9-7/8" hole to 1500' MD. Run and curt 7-5/8" surface casing. 4. ND conductor riser, N/U & test 11" x 5M Townsend BOP. 5. Drill 6-3/4" hole section to 8,900' MD. Perform Wiper trip. 6. Perform RFT logging and sidewall coring. 7. Make cleanout run 8. POOH laying down drill pipe. 9. Run and cmt 4-1/2" production casing. 10. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR + Res 2. Production Hole: GR+ Res + Den/Neu (LVD). ECS/ADT+ XPT + Sidewall Coring (eline) 3. Mud loggers from surface casing point to TD. Page 7 Version 0 March, 2017 Kalotsa #3 Drilling Procedure Rev 0 Hilcorp E.� c2jx 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. • BOPs shall be tested at (2) week intervals during the drilling of Kalotsa #3. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • 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 5/10 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. • 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. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Regulation Variance Requests: • Diverter waiver requested due to the recent drilling of Kalotsa #1 and Kalotsa #2 nearby (-50' away). ✓ No issues were experienced while drilling the surface hole. Surface casing for these wells were set at 1500' TVD. Surface casing is requested to be set at 1,381' TVD on Kalotsa #3. No shallow hydrocarbon zones will be penetrated. Q w -(( ah Pecs Page 8 Version 0 March, 2017 n Hilcorp ay Summary of BOP Equipment and Test Requirements Kalotsa #3 Drilling Procedure Rev 0 Hole Section Equipment Test Pressure (psi) 9-7/8" • No diverter utilized n/a • 11" x SM Townsend Annular BOP • 11" x 5M Townsend Double Ram Initial Test: 250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 6-3/4" 11" x 5M Townsend Single Ram • 3-1/8" 5M Choke Line Subsequent Tests: • 2-1/16" x 5M Kill line 250/3500 • 3-1/8" x 2-I/16" 5M Choke manifold (Annular 2500 psi) • Standpipe, floor valves, etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 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 9 Version 0 March, 2017 Kalotsa #3 Drilling Procedure Rev 0 Hilcorp Fongy Compavy 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 Saxon 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. • HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 strokes with 5-1/2" liners. Page 10 Version 0 March, 2017 H Hilcorp Cne� Company 10.0 N/U 16" Conductor Riser 10.1 N/U 16" Conductor Riser Kalotsa #3 Drilling Procedure Rev 0 • 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. • Ensure flowline outlet installed so that enough slope exists to carry cuttings to the shakers. • Consider adding additional drainage points at the bottom of the conductor riser if deemed necessary. • R/U fill up line to conductor riser. 10.2 Set wearbushing in wellhead. Page 11 Version 0 March, 2017 0 Hilcorp 10.3 Rig Orientation on Kalotsa pad: Kalotsa #3 Drilling Procedure Rev 0 Page 12 Version 0 March, 2017 a Drillinging Procedure dure Rev 0 HileOlp � car 11.0 Drill 9-7/8" Hole Section 11.1 P/U 9-7/8" directional drilling asst': • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TEA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 9-7/8" BHA (GR and Res are included in below BHA): - COMPONENT him 1 DATA 9-718" PDC OD 6.020 M 2250 Gauge 9.875 Weight 83.45 Tep P 4-1i2" REG Length 0.89 CaanutaVW7 0.89 2 T SperryDrill lobe 718 - 7.5 Stg 7.000 4.952 95.69 B 4-112" IF 30.00 30.89 Stabilizer 9.625 3 6-3'4" integral Blade 9 3+4" 6.760 2.500 9.750 105.59 8 4-1? - IF 6.99 37-88 4 6-3`4" Float Sub 6.800 2.375 108.67 8 4-1,2" IF 3.00 40.88 5 6 34' DM Collar (Directional) 6.720 3.125 103.40 B 4-12" IF 920 50.08 6 6 34" DGR Collar (Gamma) 6.710 1.920 97.80 B 4-1/2" IF 6.50 56.58 7 63'4"EWR-P4 collar(Resissivity)' 6.710 2.000 104.30 B4-12"IF 12.00 66.58 8 6 34" PWD Collar (Pressure) 6.720 1.905 96.30 8 4-112" IF 4.44 73.02 9 6 3•'4" HCIM Collar (Processor) 6.750 1.920 101.70 B 4-12" IF 6.50 79.52 10 6 3+4" TM Collar (Telemetry) 6.550 3.250 103.60 8 4412" IF 9.90 89.42 11 6.75" NM Flex Collar 6.450 2.875 8923 B 4-112" IF 30.00 119.42 12 X -Over Sub 4-112 IF x CDS 40 6.450 2.625 9E.91 B 4-5" DS 40 3.00 122 42 13 3 jts 4-1,2" HW DP 4.500 2.813 36-86 93.00 215.42 14 X -Over Sub CDS 40 x 4-1121F 6.300 2.625 87.79 8 4-112' IF 3.00 218.42 15 6-1r4"Weatherford Jar 6270 2250 91:68B 4-12- 30.00 248.42 16 X -Over Sub 4-112 IF x CDS 40 6230 2.625 85.44 B 4.5" CDS40 3.00 251.42 17 51ts 4-V2"HWDP 4.500 2.813 36.86 1 155.00 406-42 yuo.r< I Page 13 Version 0 March, 2017 ff Hilcorp Energy Ctix 11.3 Primary Bit: PRODUCT SPECIFICATIONS Cutu r Type Sclectcuga IADC Code h1323 Body Type MATRIX Total Cutler Count 46 Curer Distribution limen Jt= Face a 28 Gaugc 12 0 Up Drill 6 0 Number of Lnrpe Nozzles 6 Number of Medium Nozzles 0 Numb" .1'small Nozzlca 0 Number of Micro Nozzks 0 Number of Porta (Sin) 0 Number ofRcpiaccable Parts (Size) 0 Junk Sim Arca Isq in) 16.71 Nmmalired Face volume 4$.45"% API Connection 4-1:2 RSG. PIN Recommended Make -Up Torque• 12,461 - 17,766 Ft•tlu. Nominal Dimensions•• Makc,Up Face to Nosc 10.91 in -275 on Gauge L"jult 2,5 in • fid mm Sleeve Length 0 m - 0 mm Shank Diameter 6 in - 152 nor Break Out PlatelMal.R+I,cgacYO) is 1954114401 Approximate Shipping weight 2501,6.-113K6. SPECIAL FEATURES Up -Drill Curers m Gage Pa&, t i 16- Relieved Gagc Kalotsa #3 Drilling Procedure Rev 0 Material #771527 -Ina rNd& mcammrnded mairrup mrqur ix a fuarti m al dx bit I.D. and aqua] hie sub O.D. ulilir d m rp:cifed in API RM Sechoa A.S.Z. •'IArign dimrus:m. u<nrnnimi and nu} vvy dishtly ren a.n. .n d pndnn. Hanihumm ihiil hits and Semler: nadrh.sonaruawly Termed mut [eared. Product apsifxaricra may chuap: without notice, C 2013 Halliburton. All rights reserved. Sales of Halliburton products and services will be in accord solely with the terns and conditions contained in the conuact bdxcca Halliburton and the cuslomcr that is applicable to the sale. Page 14 Version 0 March, 2017 N Hilcorp Kalotsa #3 Drilling Procedure Rev 0 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 9-7/8" hole section to 1,500' MD/ 1,381' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale between 1400' MD and 1600' MD. • Take MWD surveys every stand drilled (60' intervals). 11.7 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 I API FL H 120-1500' 1 8,8-9.5-1 85-150 1 20-40 25-45 1 <10 1 8.5-9.0 Page 15 Version 0 March, 2017 K Hilcorp E�Cavpr" Kolotsa #3 Drilling Procedure Rev 0 System Formulation: Aquagel + FW spud mud Product FRESH WATER 0.905 bbl SODA ASH 0.5 ppb AQUAGEL 12-15 ppb CAUSTIC SODA 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC -L /DEXTRID LT if required for <12 FL ALDACIDE G 0.1 ppb X -TEND II 0.02 ppb 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. Page 16 Version 0 March, 2017 H Hilcorp races C mcm,y 12.0 Run 7-5/8" Surface Casing 12.1 R/U and pull wearbushing. Kalotsa #3 Drilling Procedure Rev 0 12.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill -up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • 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: • (1) Shoe joint w/ float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end & thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 7-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. • 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. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 1 7,630 ft -lbs Page 17 Version 0 March, 2017 ff Hi1COrp EMW e�vero Outside Diameter Nominal Weight Plain End Weight Steel Grade Tension Yield Available Seamless TYPE: BTC Kalotsa #3 Drilling Procedure Rev 0 Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY 7.625 in Wall Thickness 29,701Wit Nominal ID 29.06 lbs/ft Nominal cross section L80 Minimum Yield 683,000 in IDternal Pressure Yield Yes Available Welded Coupling Reg OD 8.500 in Threads per in Steel Grade LBO Coupling Min Yield Joint Strength 721,000 Ills 0.375 in API Drift Diameter 6.875 in Alternative Drift Diameter 8.541 in PERFORMANCE 80,000 psi Minimum Ultimate 6,890 Py Collapse Pressure No CONNECTION DATA GEOMETRY 5 Thread turns [[take up PERFORMANCE 80,000 psi Coupling Min Ultimate Internal Pressure Resistance 6.750 in 111.21. 95,000 psi 4,790 psi 1 95,000 psi 6,890 psi 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 PIU 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 18 Version 0 March, 2017 U Hilcorp cn� c,2,T 13.0 Cement 7-5/8" Surface Casing Kalotsa #3 Drilling Procedure Rev 0 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 cut unit at acceptable rates. • Pump 20 bbls of freshwater through all of Schlumberger's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement PUMP. • 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 + 50% 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: 120' x .0932 bpf = 11.2 63 16" Conductor x 7-5/8" casing annulus: 12.0 ppg LEAD: (1500' —120') x .0382 bpf x 79 444 9-7/8" OH x 7-5/8" Casing 1.5 = annulus: Total LEAD: 90.2 506.4 ft3 15.4 ppg TAIL: (1500'-1000') x .0382 bpf x 28.7 161 9-7/8" OH x 7-5/8" Casing 1.5 = annulus: 15.4 ppg TAIL: 80 x .04591 bpf = 3.7 21 7-5/8" Shoe track: ti. Lv Total TAIL: 34.2 bbl 182 ft3 Page 19 Version 0 March, 2017 aoSsK I`1 J U H11COI'p Cement Slurry Design: Kalotsa #3 Drilling Procedure Rev 0 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: 1500'- 80' = 1420'x.04591 bpf = 65 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. Page 20 Version 0 March, 2017 Lead Slurry (1000' MD to surface) Tail Slurry (1000'to 150(' MD) System Extended Conventional Density 12 Ib/gal 15.4 lb/gal Yield 2.46 ft3/sk V 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk 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 Additives D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC 5002 CaC12 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaC12 0.1 % BWOC 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: 1500'- 80' = 1420'x.04591 bpf = 65 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. Page 20 Version 0 March, 2017 U Hilcorp E� C-Vay Kalotso #3 Drilling Procedure Rev 0 13.13 Do not overdisplace by more than'/2 shoe track volume. Total volume in shoe track is 3.7 bbls. 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. Be prepared with small OD top out tubing in the event atop 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: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the successor problems during the cement job Page 21 Version 0 March, 2017 H HilcmEe Came=m 14.0 BOP N/U and Test Kalotsa #3 Drilling Procedure Rev 0 14.1 N/U Seaboard multi -bowl wellhead assy. Install 7-5/8" packoff P -seals. Test to 3000 psi. 14.2 N/U 11" x 5M Townsend BOP as follows: • BOP configuration from Top down: 11" x 5M Townsend Type 90 annular BOP/11" x 5M Townsend Model 82 double ram /11" x 5M mud cross/11" x 5M Townsend Type 82 single ram • Double ram should be dressed with 4-1/2" solid body rams in top cavity, blind ram in btm cavity. • Single ram should be dressed with 4-1/2" solid body rams • N/U bell nipple, install flowline. • Install (2) manual valves & a check valve on kill side of mud cross. • 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). • Test BOP to 250/3500 psi for 5/10 min. Test annular to 250/2500 psi for 5/10 min. • 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. Page 22 Version 0 March, 2017 U Hilcorp F'i W Ca.2 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. Kalotsa #3 Drilling Procedure Rev 0 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 4.5" 16.0 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 23 Version 0 March, 2017 NNW ODOM Hilcorp eonsr compwy 15.8 6-3/4" BHA: Kolotsa #3 Drilling Procedure Rev 0 COMPONENT t Description SWIM HOBS MMD54 Numbor .r 47W- 1.500 8750 54.37P 312" REG 0.80 0-80 2 4 3/4' SperryDrill Lobe 5'6. 8.3 stg 4.750 2.794 44.57 8 312" IF 26.70 27.50 Stabilaer 6.375 3 4 34' NM Integral Blade Stabilizer 4,750 2.313 6.500 46.07 B 31±2" IF 5.60 33.10 4 4 314' DM Collar (Directional) 4,750 2.610 47.00 B 31'2" IF 9.18 42.28 5 4 3'4' PWD 25NSI (Pressure) 4.750 1.250 47.90 B NC 38 9.23 51.51 6 Inkne Stabilizer (ILS) 4,750 1.250 6.500 56.21 8 312" IF 3,00 54.51 7 4 34" SP4 (Resistroly"Gamma) • 4.750 1.250 48.20 B NC 38 22.50 77.02 8 In:ne Stabilizer (ILS) 4.750 1.250 6.500 56.21 B 3 t2" IF 3.00 80.02 9 4 3'4' ALD Collar(Density} 4 750 1.250 6.375 45.50 1 B NC 38 14.35 94.37 Stabileer 6.375 10 4 3'4" CTN Collar (Porosity) 4,750 1.250 50.50 B NC 38 11.14 105.51 11 4 34" TM Collar (Telemetryl 4.750 2.812 46.10 B NC 38 10.86 116.37 12 4.3+4" NM Flex 4.750 2.313 46.07 B 31.2" IF 30.00 146.37 13 4 3'4" NM Flex 4.750 2.313 46.07 B 312" IF 30.00 176.37 14 4 3'4` NM Flex 4.750 2 313 46.07 B 31?2" IF 30.00 208.37 15 4 34' Float Sub 4 750 2.250 46.94 8 3 t 2' IF 2.50 208.87 16 4 1'2' IF P to XT -39 8 XO Sub 4.750 2-500 43.66 8 4" XT39 1.67 0.54 t7 t p 4" "DP XT -39 4.000 2 563 25.24 31.50 2 04 18 4 3'4` Hydraulic Jar 4,635 2.250 13.95 8 4' XT39 29.30 1.34 !37 19 4 ITS 4' HW DP XT39 6.000 2563 25.24 12600 .3420 4" DP XT39 d.000 3.240 1473 31.50 8.84 ire a 428.84 Page 24 Version 0 March, 2017 a Drillinging Procedure dure Rev 0 Hilcorp Enew C-Prw 15.8 6-3/4" BHA: COMPONENTDATA hem I Serial Number HD6^a EIJi•50 FDC otl ., (in) 4.500 10 (in) 1.563 Gauge (in) 1 6750 Weight ([bpi) 47.67 Top Connez6on P 3• r2" REG Length (III 0.75 cumulAti" Length ft= 0.75 2 S' SperryDrill Lobe &7 - 6-0 stg 5.000 3.120 48.00 8 3,10 IF 24.00 24.75 Stablzer 6.560 :+. Float Sub 4.750 2.250 4684 83-11ZIF 225 27,00 4 Welded Blade Stabilizer 4,640 2,000 6.500 ,'52 00 B 3 -Ur IF 5.00 32.00 - 4 314' DM collar 4.730 1.25D i 47.00 8 3-1r' IF 920 41.20 6 4 314' Slim Phase 4 Collar 4.750 1.250 i 4820 B 3 -VP IF 24.50 85.70 7 Inline Stabilizer (ILS) 4.740 1.920 6.0D0 5027 B 3-1,7 IF 3 b 69.20 8 4 314' ALD Collar 4.750 1, 5.626 45.50 8 3-1Z IF 14 00 83.20 Stabkm 5,625 9 4 314' CTN Cellar 4.750 .260 50.50 8 3-1Z IF 11.00 94.20 Ill 4 314' PWD.0.150 .250 47.90 6 3-12" IF 920 103AO 11 4 W4' TM HOC (Pu!ser) 4. -2-L 1.250 40.90 6 3-i12•' IF 11.00 11440 12 4 3/4' BAT Collar ,750 1,250 45.70 B NC 38 26.42 140.82 13 4.75" Flex caller 4.750 2.250 4684 8 3-W IF 31.00 171.62 14 4.75' Flex Collar 4.750 2.250 46.84 8 3-irr" IF 31.00 202.82 15 X-0 3112' IF Pin X 4-112" CDS 40 Box 5.250 2.210 1 6022 B 4.5' CDS40 2.75 205.67 16 6 Joaus 4-11Z HW DP 4.500 2.750 41.00 185.00 390.57 17 X•O 4112• COS -40 Pm X 3172' IF box 5.300 2.250 61,64 6 a. v2" IF 2.75 393.32 18 4 W4" Weatherford Hyd Jar 4,750 2.250 40.84 B 3.112" IF 30.00 423.32 19 X -O 3-10 IF Pin X 4.112" CDS-40 B 5.300 2.750 54.94 B 4.5' CD340 2.75 428.07 20 13 Joints 4-112' NWOP 4.500 2.750 41.00 1 400.00 826.07 Bit Number Nozzba Bil Slze ( :6.750 TFA Manufacturer : HDSS Dull Grade b1 Model : EM65D Dull Grade Out 6X10 (In2) :04602 Page 24 Version 0 March, 2017 a Drillinging Procedure dure Rev 0 Hilc Comorp T 15.9 Primary Bit: PRODUCT SPE:C117CATIONS Cutter Type X3 • Extreme Drilling IADC Code M323 Hody Type MATRIX Total Culler Count 33 Cuero Distribution U= JSWu Face 4 13 Gauge n n Up Drill 5 0 Numberof Large Noulos 0 Number of Wdium Nozzles (I NumberotSmall Norrlex h Number ofMicm Nozzles 0 Number of Pans (Sim) 0 Numhcrof Rcplaccablr Pons (Size) 0 Junk Slot Arca 3sq in) 9.68 Nmmahzed Fare Volume 34.6911 API Connection 3-1:2 REG. PIN Recurnmattded Make -Up Torque' 5,173— 7,665 R -Un. Nominal Dimensions" Make -Up Face to Nose 9.42 in -?i9 rant Gauge Length 2 in • % mm Slccse Length 0 in -C mm Siwrk Diameter 4S in - 114 into Rnutk Out Ppnc(Mar.M•T.e(tacyM) ILt195Y44030 Appmxin ure Shipping weight 9OLbs. - 4)Kg. SPIECIAL FEATuRF.S Up -Drill CBOcrson Gngc Pads, 1 AV' Stepped Gigc.Optimizcd Dual Row -'D" Feature Material #761302 'Bit aperi0c mrarmnrndcd mntrup torque 6 a fwmtiwn of the bit I.D. and •nwai bit w* O.D. wti0itod n npxifxd in,lPt RPA; Section X8.2. 'a Design dimensinnx lee nxmimrE and,.y rare alightly rm manw(ncn"rcd pwdw c rinlliluwrin Drill Rim and Services "th we rontinuuauly rc,ic l nwd rc6nd. P1060 ar4eilnbti[Mt wily Ow"K -'Mout "'Mier. C 2013 Halliburton. All rights resen'CA, Sales of Holliburton products and serviws wit] be in accord solely with the terms and conditions contained in the contract between Hallibrton and the customer that is applicable to the sale. Page 25 Version 0 March, 2017 H EMUC rp WC" 15.10 6-3/4" hole section mud program summary: Kalotsa #3 Drilling Procedure Rev 0 Weighting material to be used for the hole section will be 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: System Formulation: 6% KCL EZ Mud DP Product Mud Water Plastic KCI 22 ppb (29K chlorides) Caustic MD BARAZAN D+ Viscosity EZ MUD DP yield Point pH HPHT PAC -L Weight BARACARB 5/25/50 Viscosity BAROID 41 as required for a 9.0 —10.0 ppg ALDACIDE G 1500'- 8.900' 9.0— 10.0 40-53 15-25 15-25 8.5-95 < 11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCI 22 ppb (29K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb (initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC -L 1 ppb BARACARB 5/25/50 15 - 20 ppb (5 ppb of each) BAROID 41 as required for a 9.0 —10.0 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 15.11 TIH w/ 6-3/4" directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.12 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. 15.13 Drill out shoe track and 20' of new formation. 15.14 CBU and condition mud for FIT. Page 26 Version 0 March, 2017 U Hilcorp Ro �-c Y 15.15 Conduct FIT to 13.5 ppg EMW. Kalotsa #3 Drilling Procedure Rev 0 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(1381/7808) = 0.71 15.16 Drill 6-3/4" hole section to 8,900' MD / 7,808' TVD • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 225 - 300 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every 100' drilled. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. 15.17 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 15.18 TOH with the drilling assy, standing back drill pipe. 15.19 LD BHA, RU E -line to perform RFT logging and sidewall coring. 15.20 RD loggers, PU 6-3/4"clean out BHA, and TIH to TD. 15.21 Pump sweep, CBU and condition mud for casing run. 15.22 POOH LDDP and BHA 15.23 4-1/2" pipe rams previously installed in BOP stack and tested. Page 27 Version 0 March, 2017 U Hilcorp 15.15 Conduct FIT to 13.5 ppg EMW. Kalotsa #3 Drilling Procedure Rev 0 Note: Offset field test data predicts frac gradient at the 7-518" shoe to be b tween 11 -13 ppg EMW. A 13.5 ppg FIT results in a 4 ppg kick margin while drilling wit he planned MW of 9.5 PPS (� Kick tolerance = (13.5-9.5)X(1381/7808) = 0.71 a 'h 15.16 Drill 6-3/4" hole section to 8,900' MD / 7,808' TV D�v • Pump sweeps and maintain mud rheology to ensure ffective hole cleaning. • Pump at 225 - 300 gpm. Ensu/hakeienscreens a set up to handle this flowrate. • Keep swab and surge pressuresn trip ' g.• Make wiper trips every 500' uco itions dictate otherwise. • Ensure shale shakers are functirly. Check for holes in screens on connections. • Adjust MW as necessary to mae stability. Keep HTHP fluid loss < 10. • Take MWD surveys every otheilled. Surve scan be taken more frequentlyy if deemed necessary.• Take (3) sets of formation cam20'. 3 3-0 15.17 At TD; pump sweeps, CBU, 15.18 TOH with the drilling assy 15.19 LD BHA, RU E -line to 15.20 RD loggers, PU a wiper trip back to the 7-5/8" shoe. back drill pipe. RFT logging and sidewall coring. out BHA, and TIH to TD. 15.21 Pump sweep, C)dU and condition mud for casing run. 15.22 POOH LDDI5 and BHA 15.23 4-1/2" pipe rams previously installed in BOP stack and tested. Page 27 Version 0 March, 2017 16.0 Run 4-1/2" Production Casing Kalotsa #3 Drilling Procedure Rev 0 16.1. R/U Weatherford 4-1/2" casing running equipment. • Ensure 4-1/2" DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • 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: • (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). • (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 4-1/2" production casing • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 7-5/8" shoe. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 1300'. 16.5. Continue running 4-1/2" production casing 4-1/2" DWC/C HT NM torques Casing OD Minimum MaximumYield Torque 4-1/2" 5,800 ft -lbs 6,500 ft -lbs 7,200 ft -lbs Page 28 Version 0 March, 2017 H Hilctp x,22 Connection Type: DWC/C Tubing standard 4.500 3.958 0.271 12.60 12.25 3.600 Kalotsa #3 Drilling Procedure Rev 0 Technical Specifications Size(O.D.): Weight (Wall): 4-1/2 in 12.60 Ib/ft (0.271 in) Material Grade Minimum Yield Strength (psi) Minimum Ultimate Strength (psi) Pipe Dimensions Nominal Pipe Body O.D. (in) Nominal Pipe Body I.D.(in) Nominal Wall Thickness (in) Nominal Weight (lbsift) Plain End Weight (lbsJft) Nominal Pipe Body Area (sq in) Grade: L-80 "W&4w -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone- 7134753200 Fw- 7134793234 E-mail:: VAMUSAsates@rann s .com Page 29 Version 0 March, 2017 Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (Ibs) 7,500 Minimum Collapse Pressure (psi) 8,430 Minimum Internal Yield Pressure (psi) 7,700 Hydrostatic Test Pressure (psi) Grade: L-80 "W&4w -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone- 7134753200 Fw- 7134793234 E-mail:: VAMUSAsates@rann s .com Page 29 Version 0 March, 2017 Connection Dimensions 5.000 Connection O.D. (in) 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter (in) 3.94 Make-up Loss (in) 3.600 Critical Area (sq in) 100.0 Joint Efficiency (%) Grade: L-80 "W&4w -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone- 7134753200 Fw- 7134793234 E-mail:: VAMUSAsates@rann s .com Page 29 Version 0 March, 2017 Connection Performance Properties 288,000 Joint Strength (Ibs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (Ibs) 288,000 Compression Rating (Ibs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-Ibs) 6,500 Maximum Final Torque (ft-Ibs) 7,200 Connection Yield Torque (ft-Ibs) Grade: L-80 "W&4w -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone- 7134753200 Fw- 7134793234 E-mail:: VAMUSAsates@rann s .com Page 29 Version 0 March, 2017 U Hilcorp 16.6. Run in hole w/ 4-1/2" casing to the 7-5/8" casing shoe. Kalotsa #3 Drilling Procedure Rev 0 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 4-1/2" X 6-3/4" swell packer to be placed at approximately 1300'. 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. PIU 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. Page 30 Version 0 March, 2017 U Hilcorp Fm m, 17.0 Cement 4-1/2" Production Casing Kalotsa #3 Drilling Procedure Rev 0 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. • Pump 20 bbls of freshwater through all of Schlumberger's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement PSP- • Positions and expectations of personnel involved with the cmt operation. • 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 35% OH excess. Section: Calculation: Vol BBLS Vol (ft3) 7-5/8" x 4-1/2" Csg Overlap: 500' x 0.026 = 13 73 6-3/4" OH x 4-1/2" Casing: (8900 —1500) x 0.025 x 1.35 = 250 1404 Shoe Track: 80' x 0.019 = 1.5 8.5 Total Volume : 264.5 1486 iL, Page 31 Version 0 March, 2017 U Hilcorp 17.7. Drop wiper plug and displace with 6% KCI. Kalotsa #3 Drilling Procedure Rev 0 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 %2 shoe track. Shoe track volume is 1.5 bbls. 41-"J --i .alsz ge&l,a dYu. , - 1 � a� 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 3500 psi and chart for 30 minutes. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the successor problems during the cement job Send final "As -Run" casing tally & casing and cement report to mmyers@hilcorn com This will be included with the EOW documentation that ,goes to the AOGCC Page 32 Version 0 March, 2017 a Drillinging Procedure dure Rev 0 Hilcorp 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig #169 C 6 L (—r rA 4o f5 Page 33 Version 0 March, 2017 19.0 BOP Schematic Kalotsa #3 Drilling Procedure Rev 0 Ide Page 34 Version 0 March, 2017 Grade U Hilcorp Em C Pavy 20.0 Wellhead Schematic Tuwr Wax'l Nps, 136/36N 2-21/16 13 WSM x )6Mb6 2 135/85 L165N Nmilttik Urv[ Yab[7 anal 16tl)N6aa Y, 6fN0. Orly O2/165M R x 65Oliapurcturvan:op Kalotsa #3 Drilling Procedure Rev 0 Casing n.w" (w. 11 . 0 % DWC/C boa bIM x6125" PN nen axmn noao>, w/ 75/8 oa neck. a" type N a" prolde, OD NL —rt—I Page 35 Version 0 March, 2017 Kalotsa Drilling Procedure Rev 0 Hilcorp � �Yo . 21.0 Days Vs Depth 1000 2000 Y .m x L d Y L 5000 U N Y E 7000 8000 9000 10000 Page 36 Days Vs Depth 0 5 10 is 20 25 30 Days Version 0 March, 2017 Kalotsa Drilling Procedure ff Rev 0 Hilcorp a� C—P-y 22.0 Geo-Prog WELL NAME: Kalot % 209857.66 -�----- !!pELD: Ninilchik (Pax -Dionne Area) SURFACE LOCATION _ _ x-208796.30 PFE (PROPOSED): BHL: y=2233535.94 _ x=2237156.40 PAD ID Kalotsa3 PROPOSED TO 8900 MD; 7808 TVD ES7 KB: 144.5 API: TBD t I � I _ _ ESL GL: i Drill an 8900 MD grass roots well at Ninilchik Field that will target reserves in T65, and T83, T90 sands. Secondary targets include the Objective: Beluga and Tyonek T3, T6, and T140 sands. _ ANTICIPATED FORMA77ONTOPS 'EXPECTED FLUID MD TVD (F"<) SUBSEA DEPTH Est. Pressure EMW Gradient Beluga 120 3942 3,399 (3254) 1530 8.7 0.45 Beluga 135 4143 3,565 (3420) 1604 8.7 0.45 Tyonek 7X 4263 3,664 (3519) 1649 8.7 045 Tyonek T3 4465 3,831 (3686) 1724 _ 8.7 0.45 Tyonek T6 4777 4,089 (3944) 1840 8.7 -045 Tyonek 65 7539 6,460 (6315) 2907 81 0.45 Tyonek 83 7848 6,764 (6619) 3044 8.7 045 Tyonek 90 8006 6,921 (6776) 3114 87 _ 0.45 Tyonek 110 8304 7,217 (7072) 3248 8.7 - - 045 Tyonek 140 _ 8562 7,473 (7328) 3363 8.7 0.45 LVVD Data LWD Triple Com bo surface casing to TD i Other Log Data NOTES 95% 136' 1500' TD to be drilled from the Kalotsa pad and will be drilled to the north. Please protide drilling and myselfwith the location when the best looafion has been identified and staked. NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HILCORP OR THEIR PARTNERS. Page 37 Version 0 March, 2017 U Hilcorp E—W Compsey 23.0 Anticipated Drilling Hazards 9-7/8" Hole Section: Kalotsa #3 Drilling Procedure Rev 0 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 March, 2017 .✓ ff Hilcorp Kalotsa #3 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. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: 1-12S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 39 Version 0 March, 2017 ff Hilcorp F� C-P®Y 24.0 Saxon Rig 169 Layout Kalotsa #3 Drilling Procedure Rev 0 Page 40 Version 0 March, 2017 U Hilcorp Eos mT 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Kalotsa #3 Drilling Procedure Rev 0 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 I -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 March, 2017 H Hilc T c�vv,r 26.0 Choke Manifold Schematic Kalotsa #3 Drilling Procedure Rev 0 Page 42 Version 0 March, 2017 Gl RR ®_ lti �R ice— _ -- 'wA I�ii� � � 1 7� 6 Page 42 Version 0 March, 2017 U Hilcorp �= Kalotsa #3 Drilling Procedure Rev 0 27.0 Casing Design Information Calculation & Casing Design Factors Hole Size 9-7/8" Hole Size 6-3/4" Hole Size Ninilchik DATE: 03/1/2017 WELL: Kalotsa #3 FIELD: Ninilchik DESIGN BY: Monty M Myers Criteria: Mud Density: 8.8 ppg Mud Density: 10 ppg Mud Density: Drilling Mode MASP: 2733 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 2733 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.45 psi/R) and the casing evacuated for the internal stress Page 43 Version 0 March, 2017 Casing Section Calculation/Specification 1 2 3 4 Casing OD 7-5/8" 4-1/7' Top (MD) 0 0 Top (TVD) 0 0 Bottom (MD) 1,500 8,900 Bottom (ND)..._. 1,381 7,808 Length_ 1,500 8,900 Weight (ppf) 29.7 12.6 Grade L-80 L-80 Connection BTC DWC/C HT Weight w/o Bouyancy Factor(Ibs) 44,550 112,140 Tension at Top of Section (lbs) 44,550 112,140 Min strength Tension (1000 lbs) 683 288 Worst Case Safety Factor (Tension) 15.33 2.57 , Collapse Pressure at bottom (Psi) 601 3,396 Collapse Resistance w/o tension (Psi) 4,790 7,480 Worst Case Safety Factor (Collapse) 7.97 2.20 MASP (psi) 457 2,733 Minimum Yield (psi) 16,890 8,430 Worst case safety factor (Burst) 15.08' 3.08 ' Page 43 Version 0 March, 2017 d Drillinging Procedure dure 0 Rev 0 Hilcorp Enm� Company 28"0 H Hiicorp 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-3/4" Hole Section Kalotsa 43 Ninilchik MD TVD Planned Top: 0 0 Planned TD: 8900 7808 AMidnated FnrrnaNnnc and Droccuroc- Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Beluga 120 3399 1529.6 Gas SusanDionne6 9.2-9.6ppg Beluga 135 3565 1604.3 Gas 8.7 • 0.450 TyonekTX 3664 1648.8 Gas 8.7 0.450 TyonekT3 3831 1724.0 Gas 8.7 0.450 TyonekT6 4089 1840.1 Gas 8.7 0.450 Tyonek65 6460 2907.0 Gas 8.7 0.450 Tyonek83 6764 3043.8 Gas 8.7 0.450 Tyonek90 6921 3114.5 Gas 8.7 0.450 Tyonek110 7217 3247.7 Gas 8.7 OASO Tyonek 140 7473 3362.9 Gas 8.7 0.450 TD 78M 3515.0 Gas 8.7 0.450 Offset Well Mud Densities well MW range Top (TVD) Bottom (TVD) Date Susan Dionne 5 9.5-9.8ppg 1,299' 7,98T 2006 SusanDionne6 9.2-9.6ppg 1,578' 4,520' 2008 Susan Dionne 7 1 9.2 - 10.1 ppg 1,450' 7,882' 2011 Assumptions: 1. Fracture gradient at shoe (1500'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 1381 ft X 0.884 psi/ft 1221 psi 1221(psi) - [0.1(psi/ft)'1381(ft))= 1083 psi MASP from pore pressure during production mode (Complete evacuation to gas)^ 7808ft X0.450psi/ft 3514psi Downhole 3514(psi) - [0.1(psi/ft)'7808(ft))= 2733 psi Surface Summary: 1. MASP while drilling 6-3/4" production hole is governed by frac pressure at 7-5/8" shoe with entire wellbore evacuated togas Page 44 Version 0 March, 2017 H Hilcorp F� Cpx" 29.1 Kalotsa #3 Drilling Procedure Rev 0 0 W F 2.000 11 Ninilcfi�ik Unit Fes, Kalotsa 3 Alaska State Plalre Zone 4. NAD27 .4 IN—, %1.4.. I.IL 6WPDale:2Q8 017 A Page 45 Version 0 March, 2017 a Drillinging Procedure dure Rev 0 Hilcorp � ��, 30.0 Surface Plat (NAD 27) GOVT L0T 1 tour Lor 2 ----------- tour Lor /� 458' N: 2232605.58 E:209377.32 2262' FSL I. R:450F G[WEiK WNiR➢L AtYlNNJ61Ap31101f (f?SN3D11i15 PNI�R)5 SOLUTKKVfliddNGS WOt✓aNVF55TFTDAG 9RECORSAW.'iSEACQiS ARP'. AlIDZJWl1{WYS b LtX6lTTi0 E5TA8LISNTlE PtY3t1(R1 Qf V103'QN 54/_4W dWRlEPAD T:g GE•DETIC PDSIIMNOFDIDJW85 �lERLB� TO HA4E AIATIIBAfE OF 1i�UG43 Yb'NAT$IALONGIiIAE OF 951'3i35.iT2Yi 1!E AIISRA STATE PoA.1tE WDfdS'vA'ES1ASPb2•NE4AiiE N.1ad39T935 Ez1J5JBR97 EtEv. 17978'tH41'D7BJ 3.ODDR7tYiTE CY1tAETt9�f 5 M40R5TO NAD]t)1'�T_fE M11� USNGC�59fSi SCFRVAFE l`ETtSBa\ 6.6 9. 11ih-ml, Ala.La. LIA'. LAT: 60' 06' 15.47490'N LON: 151' 35 24.26431'W N: 2233535.942' E: 209857.657' 458' FWL 2262' FSL - ASP ZONE 4 NAD 27 ELEV. 126.5 (NGVD29) R13W i 1 t SCALE NILCORP ALASKA, LLC KALOTSA 93 NINILC"K ALASKA AS -BUILT SURFACE LOCATION SEC. 07 TO1S R13W SEWARD MERIDIAN, ALASKA ue+c tov.7.w Page 46 Version 0 March, 2017 H Hilcorp F� C. -pa, 31.0 Directional Plan (wp05) Kalotsa #3 Drilling Procedure Rev 0 Page 47 Version 0 March, 2017 Hilcorp Alaska, LLC Ninilchik Unit Kalotsa Plan: Kalotsa 3 Kalotsa 3 Plan: Kalotsa 3 WP05 Standard Proposal Report 01 March, 2017 HALLIBURTON Sperry Drilling Services -1 1 HALLIBURTON 0porre Drilling M 7 5/8" x 9 7/8" Project: Ninilchik Unit Site: Kalotsa Well: Plan: Kalotsa 3 Wellbore: Kalotsa 3 Plan: Kalotsa 3 WP05 Start Dir 4-/100': 250' MD, 250TVD 500 End Dir : 1107.5' MD, 1057.19' TVD Appp 2ypp WI:I.L DETAILS: Mn: Kaloge 3 NAD 1927 (NADCON COWS) Aluka lane 04 Grouts level: 126.50 +N/ -S +V -W Northing E 6' latinude Longi u& 0.00 0.00 2233535.44 209957.33 60.6'15.470N 151.35'24,271W REFERENCE INFORMATION Coonlinale (NIE) Reference: Well plan' Kalolea 3, True NOM Verlicel (rva) Reference: I(eblsa 3 W%5 ®144.50uafi Measured Depth Re2renae: "lolsa 3 M05 Q 144.SOusO Celwlallon Method: Minimum Cun'ulure 9I do Beluga 120 Beluga 135 .. . — — p0� Tyonek T%_ _ — — — — — p5p0 Tyonek T3 — pp0 5 Tyonek T6 5pp 6 pppp pyp0 1pp0 Tyonek 65 End Dir : 7843.81' MD, 6760.05' TVD — — —— -- 500 -/ Tyonek 83 — — — — — .-_K-3 wp01 T83 T9t3 — — 6 K-3 wp01 T90 Tg14 Tyonek 90 — — — — — — K-3wp01 T140 Tgt5 Tyonek 110 — -- 00,- Tyonek 140 g9p0 Total Depth: 8900' MD, 7808.36' TVD 4 1/2" x 6 3/4'' Kalotsa 3,NP05 -2000 -1500 -1000 -500 0 500 1000 1500 2600 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 Vertical Section at 342.45° (1250 usfUin) �i HALUBURTON 41/2"x63/4' ' Project: Ninilchik Unit Site: Kalotsa Well: Plan: Kalotsa 3 Wellbore: Kalotsa 3 Plan: Kalotsa 3 WP05 ao� 3 WPDS � K-3 wp01 T140 Tg15 WELL DETAnS: Plan: Kalom, 3 Ground Level: 126.50 +N/ -S +V -W NVmhm, Basting Ietldude Longitude 0.00 000 223353544 209957.33 60-6'15470N 151-35'24.271W REFERENCE INFORMATION Co-oldinate (WE) Rekrence: Wap Plan: KalOBa 3. Tme Nunn VaM .I (TVD) Reference: Ki lok.3 N 5 0144.50VA Measured Dania Refamn.: K.IaN. 3 M05 ®144.50.ft Calmlation Method: Minimum Curvature CASING DETAILS TVD TVDSS MD Size Name 1381.44 1236.94 1500.00 7-5/8 7 5/8" x 9 7/8" 7808.36 7663.86 8900.00 4-1/2 4 1/2" x 6 3/4" and Dir : 1107.5' MD, 1057.19 TVD Stan IN, 4•/100': 259 MD, 250 -TVD -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 West( -)/East(+) (500 osft/in) HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Ninilchik Unit Site: Kalotsa V4011: Plan: Kalotsa 3 Wellbore: Kalotsa 3 Design: Kalotsa 3 WP05 Local Cc -ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: Kalotsa 3 Kalotsa 3 WP05 @ 144.50usft Kalotsa 3 WP05 @ 144.50usft True Minimum Curvature Project Ninilchik Unit 18.00 Audit Notes: Map System: US Stale Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) (usft) Using Well Reference Point Map Zone: Alaska Zone 04 0.00 Using geodetic scale factor (ND) Dogleg (usft) Turn Site Kalotsa +E/ -W Rate -2.50 Rate Site Position: (usft) Northing: 2,233,473.90 Usti Latitude: 60° 6'14.861 N From: Map Fasting: 209,844.16usft Longitude: 151°35'24.501W Position Uncertainty: 0.00 Usti Slot Radius: 13-3/16" Grid Convergence: -1.38 ° (usft) (°) (°) (usft) usft Well Plan: Kalotsa 3 0.00 18.00 -126.50 Well Position +NIS 0.00 usft Northing: 2,233,535.44 usft - Latitude: 60° 6' 15.470 N 1,107.50 +E/ -W 0.00 usft Easting: 209,857.33 usft ' Longitude: 151° 35' 24.271 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 126.50 usft Wellbore Kalotsa 3 Magnetics Model Name Sample Date Declination C) BGGM2016 8/912016 15.92 Design Kalotsa 3 WP05 18.00 Audit Notes: +N/ -S +E/ -W Direction Version: (usft) (usft) Phase: Vertical Section: 0.00 0.00 Depth From (ND) Dogleg (usft) Turn +NbS +E/ -W Rate -2.50 Rate Plan Sections (usft) (usft) (°/100usft) (°AOOusft) (°1100usft) Measured 0.00 0.00 0.00 Vertical TVD Depth Inclination Azimuth Depth System (usft) (°) (°) (usft) usft 18.00 0.00 0.00 18.00 -126.50 250.00 0.00 0.00 250.00 105.50 1,107.50 34.30 342.10 1,057.19 912.69 6,476.10 34.30 342.10 5,492.18 5,347.68 7,843.81 7.00 348.55 6,760.05 6,615.55 8,014.54 7.00 348.55 6,929.50 6,785.00 8,558.59 7.00 348.55 7,469.50 7,325.00 8,900.00 7.00 348.55 7,808.36 7,663.86 Dip Angle Field Strength (°1 (nT) 73.12 55,211 PLAN Tie On Depth: 18.00 +N/ -S +E/ -W Direction (usft) (usft) (°) 0.00 0.00 342.45 Dogleg Build Turn +NbS +E/ -W Rate Rate Rate Tool Face (usft) (usft) (°/100usft) (°AOOusft) (°1100usft) V) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 237.04 -76.56 4.00 4.00 0.00 342.10 3,115.94 -1,006.42 0.00 0.00 0.00 0.00 3,573.06 -1,144.04 2.00 -2.00 0.47 178.29 3,593.45 -1,148.17 0.00 0.00 0.00 0.00 3,658.43 -1,161.33 0.00 0.00 0.00 0.00 3,699.21 -1,169.59 0.00 0.00 0.00 0.00 3111201710:29:034M Page 2 COMPASS 5000.1 Build 81 Planned Survey Halliburton H A L L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: Kalotsa 3 Company: Hiloorp Alaska, LLC TVD Reference: Kalotsa 3 WPO5 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 3 WP05 @ 144.50usft Site: Kalotsa North Reference: True Well: Plan: Kalotsa 3 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 3 Depth TVDss Design: Kalotsa 3 WP05 +E/ -W Northing Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Eastin 9 DLS Vert Section (usft) C) (<) (usft) usft (usft) (usft) (usft) (usft) -126.50 18.00 0.00 0.00 18.00 -126.50 0.00 0.00 2,233,535.44 209,857.33 0.00 0.00 100.00 0.00 0.00 100.00 -44.50 0.00 0.00 2,233,535.44 209,857.33 0.00 0.00 200.00 0.00 0.00 200.00 55.50 0.00 0.00 2,233,535.44 209,857.33 0.00 0.00 250.00 0.00 0.00 250.00 105.50 0.00 0.00 2,233,535.44 209,857.33 0.00 0.00 Start Dir4°1100': 250' MD, 250'TVD 300.00 2.00 342.10 299.99 155.49 0.83 -0.27 2,233,536.28 209,857.08 4.00 0.87 400.00 6.00 342.10 399.73 255.23 7.47 -2.41 2,233,542.96 209,855.10 4.00 7.85 500.00 10.00 342.10 498.73 354.23 20.71 -6.69 2,233,556.30 209,851.14 4.00 21.76 600.00 14.00 342.10 596.53 452.03 40.49 -13.08 2,233,576.23 209,845.23 4.00 42.55 700.00 18.00 342.10 692.63 548.13 66.71 -21.55 2,233,602.65 209,837.39 4.00 70.11 800.00 22.00 342.10 786.58 642.08 99.25 -32.06 2,233,635.43 209,827.67 4.00 104.30 900.00 26.00 342.10 877.92 733.42 137.95 -44.56 2,233,674.42 209,816.11 4.00 144.96 11000.00 30.00 342.10 966.20 821.70 182.62 -58.98 2,233,719.42 209,802.76 4.00 191.90 1,100.00 34.00 342.10 1,050.98 906.48 233.03 -75.27 2,233,770.21 209,787.69 4.00 244.88 1,107.50 34.30 342.10 1,057.19 912.69 237.04 -76.56 2,233,774.25 209,786.49 4.00 249.09 End Dir : 1107.5' MD, 1057.19' TVD 1,200.00 34.30 342.10 1,133.61 989.11 286.64 -92.58 2,233,824.22 209,771.67 0.00 301.22 1,300.00 34.30 342.10 1,216.22 1,071.72 340.27 -109.90 2,233,878.25 209,755.65 0.00 357.57 1,400.00 34.30 342.10 1,298.83 1,154.33 393.89 -127.22 2,233,932.28 209,739.62 0.00 413.92 1,500.00 34.30 342.10 1,381.44 1,236.94 447.52 .144.54 2,233,986.30 209,723.60 0.00 470.27 7 6/8" x 9 7/8" 1,600.00 34.30 342.10 1,464.05 1,319.55 501.14 -161.86 2,234,040.33 209,707.57 0.00 526.62 1,700.00 34.30 342.10 1,546.65 1,402.15 554.77 -179.18 2,234,094.35 209,691.55 0.00 582.97 1,800.00 34.30 342.10 1,629.26 1,484.76 608.39 -196.50 2,234,148.38 209,675.52 0.00 639.33 1,900.00 34.30 342.10 1,711.87 1,567.37 662.01 -213.82 2,234,202.40 209,659.50 0.00 695.68 2,000.00 34.30 342.10 1,794.48 1,649.98 715.64 -231.15 2,234,256.43 209,643.47 0.00 752.03 2,100.00 34.30 342.10 1,877.09 1,732.59 769.26 -248.47 2,234,310.46 209,627.45 0.00 808.38 2,200.00 34.30 342.10 1,959.70 1,815.20 822.89 -265.79 2,234,364.48 209,611.42 0.00 864.73 2,300.00 34.30 342.10 2,042.31 1,897.81 876.51 -283.11 2,234,418.51 209,595.39 0.00 921.08 2,400.00 34.30 342.10 2,124.92 1,980.42 930.14 -300.43 2,234,472.53 209,579.37 0.00 977.43 2,500.00 34.30 342.10 2,207.53 2,063.03 983.76 -317.75 2,234,526.56 209,563.34 0.00 1,033.79 2,600.00 34.30 342.10 2,290.14 2,145.64 1,037.39 -335.07 2,234,580.59 209,547.32 0.00 1,090.14 2,700.00 34.30 342.10 2,372.75 2,228.25 1,091.01 -352.39 2,234,634.61 209,531.29 0.00 1,146.49 2,800.00 34.30 342.10 2,455.36 2,310.86 1,144.64 -369.71 2,234,688.64 209,515.27 0.00 1,202.84 2,900.00 34.30 342.10 2,537.97 2,393.47 1,198.26 -387.03 2,234,742.66 209,499.24 0.00 1,259.19 3,000.00 34.30 342.10 2,620.58 2,476.08 1,251.89 -404.35 2,234,796.69 209,483.22 0.00 1,315.54 3,100.00 34.30 342.10 2,703.19 2,558.69 1,305.51 421.67 2,234,850.71 209,467.19 0.00 1,371.90 3,200.00 34.30 342.10 2,785.80 2,641.30 1,359.14 -438.99 2,234,904.74 209,451.17 0.00 1,428.25 3,300.00 34.30 342.10 2,868.41 2,723.91 1,412.76 456.31 2,234,958.77 209,435.14 0.00 1,484.60 3,400.00 34.30 342.10 2,951.02 2,806.52 1,466.39 473.63 2,235,012.79 209,419.12 0.00 1,540.95 3,500.00 34.30 342.10 3,033.63 2,889.13 1,520.01 490.95 2,235,066.82 209,403.09 0.00 1,597.30 3,600.00 34.30 342.10 3,116.24 2,971.74 1,573.64 -508.27 2,235,120.84 209,387.07 0.00 1,653.65 3,700.00 34.30 342.10 3,198.85 3,054.35 1,627.26 -525.59 2,235,174.87 209,371.04 0.00 1,710.00 3,800.00 34.30 342.10 3,281.46 3,136.96 1,680.89 542.91 2,235,228.89 209,355.02 0.00 1,766.36 3,900.00 34.30 342.10 3,364.07 3,219.57 1,734.51 -560.23 2,235,282.92 209,338.99 0.00 1,822.71 311/2017 10:29:03AM Page 3 COMPASS 5000.1Build 81 Planned Survey Halliburton HA L L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US+CANADA Local Co-ordinate Reference: Well Plan: Kalotsa 3 Company: Hilcorp Alaska, LLC TVD Reference: Kalotsa 3 WP05 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 3 WP05 @ 144.50usft Site: Kalotsa North Reference: True Well: Plan: Kalotsa 3 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 3 TVDss +N/ -S Design: Kalotsa 3 WP05 Northing Easting Planned Survey -- Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (I V) (usft) usft (usft) (usft) (usft) (usft) 3,233.50 3,916.86 34.30 342.10 3,378.00 3,233.50 1,743.55 -563.15 2,235,292.03 209,336.29 0.00 1,832.21 Beluga 120 4,000.00 34.30 342.10 3,446.68 3,302.18 1,788.14 -577.55 2,235,336.95 209,322.97 0.00 1,879.06 4,100.00 34.30 342.10 3,529.29 3,384.79 1,841.76 -594.87 2,235,390.97 209,306.94 0.00 1,935.41 4,117.81 34.30 342.10 3,544.00 3,399.50 1,851.31 -597.96 2,235,400.59 209,304.09 0.00 1,945.44 Beluga 135 4,200.00 34.30 342.10 3,611.90 3,467.40 1,895.39 -612.19 2,235,445.00 209,290.92 0.00 1,991.76 4,237.65 34.30 342.10 3,643.00 3,498.50 1,915.57 -618.71 2,235,465.34 209,284.89 0.00 2,012.98 Tyonek TX 4,300.00 34.30 342.10 3,694.51 3,550.01 1,949.01 -629.51 2,235,499.02 209,274.89 0.00 2,048.11 4,400.00 34.30 342.10 3,777.12 3,632.62 2,002.64 -646.83 2,235,553.05 209,258.87 0.00 2,104.47 4,439.80 34.30 342.10 3,810.00 3,665.50 2,023.98 -653.73 2,235,574.55 209,252.49 0.00 2,126.89 Tyonek T3 4,500.00 34.30 342.10 3,859.73 3,715.23 2,056.26 -664.15 2,235,607.08 209,242.84 0.00 2,160.82 4,600.00 34.30 342.10 3,942.34 3,797.84 2,109.89 -681.47 2,235,661.10 209,226.82 0.00 2,217.17 4,700.00 34.30 342.10 4,024.95 3,880.45 2,163.51 -698.79 2,235,715.13 209,210.79 0.00 2,273.52 4,752.11 34.30 342.10 4,068.00 3,923.50 2,191.46 -707.82 2,235,743.28 209,202.44 0.00 2,302.89 Tyonek T6 4,800.00 34.30 342.10 4,107.56 3,963.06 2,217.13 -716.12 2,235,769.15 209,194.77 0.00 2,329.87 4,900.00 34.30 342.10 4,190.17 4,045.67 2,270.76 -733.44 2,235,823.18 209,178.74 0.00 2,386.22 5,000.00 34.30 342.10 4,272.78 4,128.28 2,324.38 -750.76 2,235,877.20 209,162.72 0.00 2,442.57 5,100.00 34.30 342.10 4,355.39 4,210.89 2,378.01 -768.08 2,235,931.23 209,146.69 0.00 2,498.93 5,200.00 34.30 342.10 4,438.00 4,293.50 2,431.63 -785.40 2,235,985.26 209,130.67 0.00 2,555.28 5,300.00 34.30 342.10 4,520.61 4,376.11 2,485.26 -802.72 2,236,039.28 209,114.64 0.00 2,611.63 5,400.00 34.30 342.10 4,603.22 4,458.72 2,538.88 -820.04 2,236,093.31 209,098.62 0.00 2,667.98 5,500.00 34.30 342.10 4,685.83 4,541.33 2,592.51 -837.36 2,236,147.33 209,082.59 0.00 2,724.33 5,600.00 34.30 342.10 4,768.44 4,623.94 2,646.13 -854.68 2,236,201.36 209,066.57 0.00 2,780.68 5,700.00 34.30 342.10 4,851.05 4,706.55 2,699.76 -872.00 2,236,255.38 209,050.54 0.00 2,837.03 5,800.00 34.30 342.10 4,933.66 4,789.16 2,753.38 -889.32 2,236,309.41 209,034.52 0.00 2,893.39 5,900.00 34.30 342.10 5,016.27 4,871.77 2,807.01 -906.64 2,236,363.44 209,018.49 0.00 2,949.74 6,000.00 34.30 342.10 5,098.88 4,954.38 2,860.63 -923.96 2,236,417.46 209,002.47 0.00 3,006.09 6,100.00 34.30 342.10 5,181.49 5,036.99 2,914.26 -941.28 2,236,471.49 208,986.44 0.00 3,062.44 6,200.00 34.30 342.10 5,264.10 5,119.60 2,967.88 -958.60 2,236,525.51 208,970.42 0.00 3,118.79 6,300.00 34.30 342.10 5,346.71 5,202.21 3,021.51 -975.92 2,236,579.54 208,954.39 0.00 3,175.14 6,400.00 34.30 342.10 5,429.32 5,284.82 3,075.13 -993.24 2,236,633.57 208,938.37 0.00 3,231.50 6,476.10 34.30 342.10 5,492.18 5,347.68 3,115.94 -1,006.42 2,236,674.68 208,926.17 0.00 3,274.38 Start Dir 2-1100': 6476.1' MD, 5492.18 -TVD 6,500.00 33.82 342.13 5,511.98 5,367.48 3,128.68 -1,010.53 2,236,687.51 208,922.37 2.00 3,287.76 6,600.00 31.82 342.24 5,596.01 5,451.51 3,180.28 -1,027.12 2,236,739.50 208,907.03 2.00 3,341.97 6,700.00 29.82 342.37 5,681.88 5,537.38 3,229.09 -1,042.69 2,236,788.67 208,892.63 2.00 3,393.20 6,800.00 27.83 342.51 5,769.49 5,624.99 3,275.06 -1,057.24 2,236,834.97 208,879.19 2.00 3,441.41 6,900.00 25.83 342.68 5,858.72 5,714.22 3,318.12 -1,070.74 2,236,878.34 208,866.73 2.00 3,486.54 7,000.00 23.83 342.87 5,949.48 5,804.98 3,358.22 -1,083.18 2,236,918.73 208,855.26 2.00 3,528.53 7,100.00 21.83 343.09 6,041.64 5,897.14 3,395.32 -1,094.54 2,236,956.09 208,844.80 2.00 3,567.32 7,200.00 19.83 343.36 6,135.10 5,990.60 3,429.36 -1,104.80 2,236,990.37 20883536 2.00 3,602.88 3112017 10:29:03AM Page 4 COMPASS 5000.1 Build81 f Halliburton HA L L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US +CANADA Local Co-ordinate Reference: Well Plan: Kalotsa 3 Company: Hilccrp Alaska, LLC TVD Reference: Kalotsa 3 WP05 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 3 WP05 @ 144.50usft Site: Kalotsa North Reference: True Well: Plan: Kalotsa 3 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 3 Depth Inclination Azimuth Design: Kalotsa 3 WP05 +N1 -S +EI -W Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N1 -S +EI -W Northing Easting DLS Vert Section (usft) (') (') (usft) usft (usft) (usft) (usft) (usft) 6,085.24 7,300.00 17.84 343.68 6,229.74 6,085.24 3,460.31 -1,113.97 2,237,021.54 208,826.94 2.00 3,635.15 7,400.00 15.84 344.08 6,325.45 6,180.95 3,488.14 -1,122.01 2,237,049.55 208,819.57 2.00 3,664.11 7,500.00 13.84 344.60 6,422.10 6,277.60 3,512.80 -1,128.93 2,237,074.37 208,813.24 2.00 3,689.71 7,517.39 13.50 344.70 6,439.00 6,294.50 3,516.76 -1,130.02 2,237,078.35 208,812.25 2.00 3,693.81 Tyonek 65 7,600.00 11.85 345.28 6,519.60 6,375.10 3,534.26 -1,134.72 2,237,095.96 208,807.97 2.00 3,711.92 7,700.00 9.86 346.24 6,617.80 6,473.30 3,552.51 -1,139.37 2,237,114.32 208,803.77 2.00 3,730.71 7,800.00 7.87 347.67 6,716.60 6,572.10 3,567.51 -1,142.87 2,237,129.40 208,800.63 2.00 3,746.07 7,826.63 7.34 348.18 6,743.00 6,598.50 3,570.95 -1,143.60 2,237,132.86 208,799.98 2.00 3,749.58 Tyonek 83 7,843.81 7.00 348.55 6,760.05 6,615.55 3,573.06 -1,144.04 2,237,134.97 208,799.59 2.00 3,751.71 End Dir : 7843.81' MD, 6760.05' TVD 7,900.00 7.00 348.55 6,815.82 6,671.32 3,579.77 -1,145.40 2,237,141.71 208,798.40 0.00 3,758.52 7,984.82 7.00 348.55 6,900.00 6,755.50 3,589.90 -1,147.45 2,237,151.89 208,796.59 0.00 3,768.80 Tyonek 90 8,000.00 7.00 348.55 6,915.07 6,770.57 3,591.71 -1,147.81 2,237,153.71 208,796.27 0.00 3,770.64 8,014.54 7.00 348.55 6,929.50 6,785.00 3,593.45 -1,148.17 2,237,155.46 208,795.96 0.00 3,772.40 8,100.00 7.00 348.55 7,014.33 6,869.83 3,603.66 -1,150.23 2,237,165.71 208,794.13 0.00 3,782.76 8,200.00 7.00 348.55 7,113.58 6,969.08 3,615.60 -1,152.65 2,237,177.71 208,792.00 0.00 3,794.88 8,283.04 7.00 348.55 7,196.00 7,051.50 3,625.52 -1,154.66 2,237,187.67 208,790.23 0.00 3,804.94 Tyonek110 8,300.00 7.00 348.55 7,212.84 7,068.34 3,627.54 -1,155.07 2,237,189.71 208,789.87 0.00 3,806.99 8,400.00 7.00 348.55 7,312.09 7,167.59 3,639.49 -1,157.49 2,237,201.71 208,787.74 0.00 3,819.11 8,500.00 7.00 348.55 7,411.34 7,266.84 3,651.43 -1,159.91 2,237,213.71 208,785.61 0.00 3,831.23 8,540.96 7.00 348.55 7,452.00 7,307.50 3,656.33 -1,160.90 2,237,218.62 208,784.74 0.00 3,836.19 Tyonek 140 8,558.59 7.00 348.55 7,469.50 7,325.00 3,658.43 -1,161.33 2,237,220.74 208,784.36 0.00 3,838.33 8,600.00 7.00 348.55 7,510.60 7,366.10 3,663.38 -1,162.33 2,237,225.71 208,783.48 0.00 3,843.35 8,700.00 7.00 348.55 7,609.85 7,465.35 3,675.32 -1,164.75 2,237,237.71 208,781.35 0.00 3,855.47 8,800.00 7.00 348.55 7,709.11 7,564.61 3,687.27 -1,167.17 2,237,249.70 208,779.22 0.00 3,867.58 •8,900.00 7.00 348.55 7,808.36 • 7,663.86 3,699.21 -1,169.59 2,237,261.70 208,777.09 0.00 3,879.70 Total Depth: 89(MD, 7808.36' TVD - 4112" x 6 314" 3/1/2017 10:29:03AM pelta 5 COMPASS 5000.1 BUBd 81 HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Ninilchik Unit Site: Kalotsa Well: Plan: Kalotsa 3 Wellbore: Kalotsa 3 Design: Kalotsa 3 WP05 Targets Target Name Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: •hillmiss target Dip Angle Dip Dir. TVD +N/ -S -Shape (°) O (usft) (usft) K-3 wp01 T140 Tgt5 0,00 0.00 7,469.50 3,594.00 - plan misses target center by 65.34usft at 8550.57usft MD (7461.54 TVD, 3657.47 N, -1161.13 E) - Circle (radius 50.00) K-3 wp01 T90 Tgt4 0.00 0.00 6,929.50 3,594.40 - plan misses target center by 1.00usft at 8014.64usft MD (6929.61 TVD, 3593.46 N, -1148.17 E) - Circle (radius 50.00) (-3 wp01 T83 Tgt3 0.00 0.00 6,759.50 3,594.00 - plan misses target center by 21.19usft at 7845.86usft MD (6762.08 TVD, 3573.30 N, -1144.09 E) - Circle (radius 50.00) Casing Points Measured Vertical Depth Depth (usft) (usft) 8,900.00 7,808.36 4 1/2" x 6 3/4" 1,500.00 1,381.44 75/8"x97/8" Formations Northing Measured Vertical Depth Depth (usft) (usft) 7,517.39 6,439.00 7,826.63 6,743.00 4,439.80 3,810.00 4,752.11 4,068.00 8,540.96 7,452.00 7,984.82 6,900.00 4,237.65 3,643.00 4,117.81 3,544.00 8,283.04 7,196.00 3,916.86 3,378.00 Vertical Depth SS Tyonek 65 Tyonek 83 Tyonek T3 Tyonek T6 Tyonek 140 Tyonek 90 Tyonek TX Beluga 135 Tyonek 110 Beluga 120 Name Name Halliburton Standard Proposal Report Well Pian: Kalotsa 3 Kalotsa 3 WP05 @ 144.50usft Kalotsa 3 WP05 Q 144.50usft True Minimum Curvature +E/•W Northing Easting (usft) (usft) (usft) -1,147.84 2,237,156.00 208,796.30 -1,147.84 2,237,156.40 208,796.30 -1,147.84 2,237,156.00 208,796.30 Casing Hole (usft) Diameter Diameter 250.00 250.00 4-1/2 6-3/4 0.00 Start Dir 4°/100' : 250' MD, 250•TVD 7-5/8 9-7i8 1,057.19 237.04 -76.56 Dip 6,476.10 Dip Direction 3,115.94 Lithology (") (°) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 250.00 250.00 0.00 0.00 Start Dir 4°/100' : 250' MD, 250•TVD 1,107.50 1,057.19 237.04 -76.56 End Dir : 1107.5' MD, 1057.19' TVD 6,476.10 5,492.18 3,115.94 -1,006.42 Start Dir 20/100'; 6476.1' MD, 5492.18'ND 7,843.81 6,760.05 3,573.06 -1,144.04 End Dir : 7843.81' MD, 6760.05' TVD 8,900.00 7,808.36 3,699.21 -11169.59 Total Depth: 8900' MD, 7808.36' TVD 311/201710:29:03AM Page 6 COMPASS 5000.1 Build 81 Hilcorp Alaska, LLC Ninilchik Unit Kalotsa Plan: Kalotsa 3 Kalotsa 3 Kalotsa 3 WP05 Sperry Drilling Services Clearance Summary Anticollision Report 01 March, 2017 Cloaesl APPmxh 30 fun -A lty Swn on Canned Sarvey Data (North Ralf erenw) R¢fetenw Oaspn: Nalotw -Plan: Kaleha J-Kalolae J-1(alolaa J WPOS Well Coordinales: 2,233,535.0 N, 209,65/.33 E 160° 06' I&V" N.151° 35' 20.27-W) Del Hall naNNaa 3 WPU5 @ 10.50usn Sun Range: 0.00 W 6,900.00 uan. MesaereJ DapW. Swn Ra61ua b 1,086.20 usn. Ckamnce Factor cutoff Ie Un0m0e0. Max Elllpsa SepmaOon is unleaded Ell Scale Factor Applied Vmslon: 5000.1 Salle: 91 Scan Type: GLOBAL FILTER APPLIED: All wellpalhs within 200'+ 1MI1000 of reference Scan Type: 25.00 HALLIBURTON Bperry Drilling Be"icas Hilcorp Alaska, LLC HALLI BURTON Ninflchik Unit Anticollision Report for Plan: Kalotsa 3 - Kalotsa 3 WP05 Closets Approach 30 Proxims" Scan on Current Survey Data (North Reference) Reference Design: Kalotsa - Plan: Kaloha 3-Kalotsa 3-Kalotsa 3 WI Scan Range: 0.00 to 8,900.00 waft. Measured Depth. Scan Radius Is 1,088.20 usft . ClearanceFactorcubR is Unlimited. Max Ellipse Separation Is Unlimited Site Name Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separatlon Depth Factor Minimum Separation Warning Compulson Well Name -Wellbore Name - Design (waft) (usft) (usft) (uafi) usft Kalotsa Kalotsa i - Kalotsa 1- Kelotea l 352,93 81.56 352A8 59.57 356.87 31.067 Centre Distance Pass- Kalotse t - Kelotsa 1- Kabha 1 375.00 61.61 375.00 59.52 379.60 29.478 Ellipse Separation Pass - Kalohal-"lolsa1-Kolotsel 1,500.00 250]] 1,500.00 229.]] 1,487.62 11.940 Clearance Factor Pass- Kaloha2-Kalotsa 2-Kaloise2 257.82 30.91 257.82 29.47 25].9] 21.372 Ellipse Separation Piece, - Keloara2-Koons 2- Kappa 2 400.00 37.18 400.00 35.14 399.93 18.198 Clemente Factor Pass- Man Kaloha 4-Kalotsa 4-Kaloha4 wpW 56436 8.46 564.76 5.39 542.92 2750 Clearance Factor Pass - Susan Dionne Susan Dionne Ne -Susan Donne N6 -Susan Dionne 05 4,692.51 122.47 4,692.51 24.51 6,230.83 1.250 Centre Dishrtce Pass - Susan Dionne NB -Susan Dionne N6 -Susan Dionne N6 4,750.00 128ea 4,750.00 17.17 6,212.69 1.164 Clearence Factor Pass - Survey root orooran, From To SumeylPlan Survey Tool (use) (usft) 18.00 1.500.00 Kaosa3 WK5 MWD+SC+sag 1.500.00 8.900.00 Kalotsa 3 WP05 MWD+SC+seg Ellipse error terms are cordate, across survey lost Neon points. Calculated ellipses incorporate surface enaro. Separation is the actual distance between ellipsoids. Distance Retention centres is in. amelght line distance between wellbore centres. Clearance Factor= Distance Behreen Profiles I (Distance Between Profiles- Ellipse Separatpn). All station cooMinates were calculated using the Minimum Curvature method. 01 March, 2017 - 10:43 Page 2of4 COMPASS HALLIBURTON Anticollision Report for Plan: Kalotsa 3 • Kalotsa 3 WP05 Diradbn and Coordinates are re1a01e b Tme Nodh Ref mme. Vedidal Deeds are relative to Kabba 3 WP05 @ 144.50us0. NodhlN and Easlirg are rela0ve to Plan: Kalotsa 3. Coordinab System is US Slate Plane 1927 (Fred sdulion), Alaska Zone 04. Cental Meridien is -150.00-, Grid Convarpenoe at Sudaoe is: -1.38 -, Hilcorp Alaska, LLC Ninilchik Unit Of lAarcA, 4017 - 10:43 Pepe 3 a/4 COMPASS Ladder Plot ur 10 M� 0 LEGEND 7 00 - Kalo5a1,Kabna1,Kalcaa1 N V0 U KabEa 2, Kabtra 2,Kab6a2 VO Plsn:Kabisa4,Kalo5a4,K0b6a4vp04V0 Susan0kwm #5,8,�Dmn 46,Susa DIMM#6Vn Q350- Kabna3N?05 0 N C 0 U 0- 3000 4500 0000 7500 0 1500 Measured Depth (1500 usftrin) Of lAarcA, 4017 - 10:43 Pepe 3 a/4 COMPASS HALLIBURTON Anticollision Report for Plan: Kalotsa 3 - Kalotsa 3 WP05 rector Plot: Measured Depth versus Separation(Clearance) Factor Hilcorp Alaska, LLC Ninilchik Unit 10.00 7.50 �. 6.25 ---- - _ _ `o LEGEND m 4 500 1p° - - .. --.—._ _ $Kalosa l,Kabsa l,KabsalW Kabsa2,K8l0sa2, Kalose2V0 -Ar PIan:K8bsa4,Ka10 4,Kal0da4up04V0 dS 3.75 S,,.n OanneN6,Susrndorne56,Susan Dunne#6V0 $ Kab9 3WP05 2.50 C'allision Avoidance Req , 1.25 o Zone -Slop Onllin 0.00 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 X00 Meawal Depth (1000 usft) 01 Wa .W17- 1a43 Pegg 4 oro COMPASS Schwartz, Guy L (DOA) From: Sent: To: Subject: r f� 1 W Monty Myers <mmyers@hilcorp.com> Tuesday, March 07, 2017 1:29 PM Schwartz, Guy L (DOA) Proximity to houses at Kalotsa r r •^ J.. 1f1 x y Y F+II Ilk. GUM&►: ; 1,t,f! 1% i , • 1, • 1 r r, M" y. �rr-ryq�p�k At y i R Line I Path Measure the distance between two points on the ground r Mouse Navigation 362,66 363.81 162.79 degrees Save Clear J him y► fj �, ,• + +'tit f •t . ► y 1 1{ i • 13 fit it;�. i .t. r Mouse Navigation 362,66 363.81 162.79 degrees Save Clear J Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Tuesday, March 7, 2017 8:35 AM To: Davies, Stephen F (DOA) Subject: RE: Kalotsa #3 (PTD #217-028) - Additional Questions Attachments: Kalotsa 3 15.16 .pdf, Kalotsa 3 6.75 BHA .pdf Good morning Steve, Good catch on the BHA, I have updated the 6-3/4" BHA with labels to make it easier to see which tools house the GR tools. I have also removed the BAT tool. You are correct! That is sonic and we will not be running it in the hole on this well. We will definitely drill in accordance with the requirements of 20 AAC 25.050(c). Every other stand for us is 120', which exceeds the requirement for 100' surveys in the intentionally deviated part of the hole, so I updated the drilling program to reflect this and have attached that sheet as well. Thank you for pointing this out! We will also be sure to keep samples of the cutting for you guys, if we end up collecting them. Please let me know if you have any additional questions. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov) Sent: Friday, March 03, 2017 4:37 PM To: Monty Myers <mmyers@hilcorp.com> Subject: FW: Kalotsa #3 (PTD #217-028) - Additional Questions Monty, More questions: On page 24, 6-3/4" BHA, I don't see a gamma ray collar plainly listed. It is included in one of the other collars? I see Item #12 on that same list is a BAT collar. Isn't that a sonic tool? I didn't see sonic listed in the logging program on page One of the bullet points in Section 15.16 states: "Take MWD Surveys every other stand drilled. Surveys can be taken more frequently if deemed necessary." Please ensure that the directional surveying program for the well conforms to the requirements of 20 AAC 25.050(c). Drill cuttings samples were required for Kalotsa 1, the first well drilled from the Kalotsa Pad. If Hilcorp aqcuired samples in Kalotsa 1, then cuttings samples will not be required from development well Kalotsa 3. However, If Hilcorp elects to obtain drill cuttings samples in Kalotsa 3, then one set must be provided to the AOGCC under 20 AAC 25.070. Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Friday, March 3, 2017 3:42 PM To: Monty Myers (mmvers@hilcorp.com) <mmyers@hilcorp.com>; David Duffy (dduffv@hilcorp.com) <dduffv@hilcorp.com> Subject: Kalotsa #3 (PTD #217-028) - Question Monty and David, Will the planned Kalotsa 3 well conform to CO 701A, Rule 3, Well Spacing, Paragraph B? CO 701 A, Rule 3 Well Spacing There shall be no gas well spacing restrictions within the Affected Area, except: A) No gas well shall be drilled or completed less than 1,500 feet from the exterior boundary of the Affected Area unless the owner and landowner is the same on both sides of the line. B) No gas well shall be drilled or completed less than 1,500 feet from an uncommitted tract within the Ninilchik Unit unless the well and the uncommitted tract both lie within the same Participating Area. Thank you. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Davies, Stephen F (DOA) From: David Duffy <dduffy@hilcorp.com> Sent: Friday, March 3, 2017 4:55 PM To: Davies, Stephen F (DOA) Subject: RE: Kalotsa #3 (PTD #217-028) - Question Attachments: Ninilchik Unit Exhibit C SD -Pax PA legals 1-7-2016.pdf As discussed, here's another copy of the Susan Dionne PA exhibits. You can get a copy of DNR's most recent unit expansion decision from their website. -David From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, March 03, 2017 4:46 PM To: David Duffy <dduffy@hilcorp.com> Subject: RE: Kalotsa #3 (PTD #217-028) - Question Thank you David, I appreciate your help. Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(@alaska.Rov. From: David Duffy [mailto:dduffv@hilcorp.coml Sent: Friday, March 3, 2017 4:45 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Monty Myers <mmyers@hilcorp.com> Cc: Jacob Dunston <ldunston@hilcorp.com> Subject: RE: Kalotsa #3 (PTD #217-028) - Question Hi Steve, thanks for the email. No, Kalotsa#3 will not require a spacing exception under the CO 701 A. The TPI is more than 7000' from the nearest external boundary of the Affected Area (unit boundary). See map below. ADL390DU a e3 + E x . Line measurement (Planar) Segment: 7,058.001797 Feet Length: 7,058.001797 Feet 013W ip A .1-C, 1 2 [! 5 0539365 Legend • oma burtsce WNl:^•• e CCRI WSW11 NOIG L.1 --'—' QCIeMGm Unl; 6o:mp ADL392ABi Ninilchik Unit Kalotsa 3 o a•m Feer YipaOM OYn bn • MY' pYp O•Y. SSLSOIi The entire wellbore also is contained within the Susan Dionne PA (black hatched outlines). There are no unleased tracks within 1500'. 2 IJ p Q ADL3B9212 LC4Laa+a,Ral ,� i f '' 50075013W I, _ til ILCHY(2 ADL3662—__- 0539365 Legend • oma burtsce WNl:^•• e CCRI WSW11 NOIG L.1 --'—' QCIeMGm Unl; 6o:mp ADL392ABi Ninilchik Unit Kalotsa 3 o a•m Feer YipaOM OYn bn • MY' pYp O•Y. SSLSOIi The entire wellbore also is contained within the Susan Dionne PA (black hatched outlines). There are no unleased tracks within 1500'. 2 CD8p386 Call me if you need more info. Have a good weekend. David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffv@hilcorp.com This email may contain confidential and / or privileged information and is intended for the recipient(s) only. In the event you receive this message in error, please notify me and delete the message. From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.eovl Sent: Friday, March 03, 2017 3:42 PM To: Monty Myers <mmyers@hilcorp.com>; David Duffy<dduffy@hilcorp.com> Subject: Kalotsa #3 (PTD #217-028)- Question Monty and David, Will the planned Kalotsa 3 well conform to CO 701A, Rule 3, Well Spacing, Paragraph B? CO 701A, Rule 3 Well Spacing There shall be no gas well spacing restrictions within the Affected Area, except: A) No gas well shall be drilled or completed less than 1,500 feet from the exterior boundary of the Affected Area unless the owner and landowner is the same on both sides of the line. B) No gas well shall be drilled or completed less than 1,500 feet from an uncommitted tract within the Ninilchik Unit unless the well and the uncommitted tract both lie within the same Participating Area. 3 8 p a60592+2 `xxxG � uinJ��•� j $ . \] L....... ' ine measurement (Planar) °•�"_'' + Segment: 1,508.690884 Feet ilOYl.iii Length: 1,508.690884 Feet CD8p386 Call me if you need more info. Have a good weekend. David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffv@hilcorp.com This email may contain confidential and / or privileged information and is intended for the recipient(s) only. In the event you receive this message in error, please notify me and delete the message. From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.eovl Sent: Friday, March 03, 2017 3:42 PM To: Monty Myers <mmyers@hilcorp.com>; David Duffy<dduffy@hilcorp.com> Subject: Kalotsa #3 (PTD #217-028)- Question Monty and David, Will the planned Kalotsa 3 well conform to CO 701A, Rule 3, Well Spacing, Paragraph B? CO 701A, Rule 3 Well Spacing There shall be no gas well spacing restrictions within the Affected Area, except: A) No gas well shall be drilled or completed less than 1,500 feet from the exterior boundary of the Affected Area unless the owner and landowner is the same on both sides of the line. B) No gas well shall be drilled or completed less than 1,500 feet from an uncommitted tract within the Ninilchik Unit unless the well and the uncommitted tract both lie within the same Participating Area. 3 Thank you. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.eov. TRANSMITTAL LETTER CHECKLIST WELL NAME: ko' (CD C PTD: 'Z/ 6ZE Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD:'dz ii/ POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter — CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - _ _) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sam le intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool NINILCHIK, BELUGA-TYONEK GAS - 562503 Well Name: KA<ALOTS$A 3 Program DEV Well bore seg ❑ PTD#:2170280 Company HILCORP ALASKA LLC Initial ClassfFype __DEV / PEND GeoArea 820 Unit 5JA32 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31,05,0300. 1..A),(j.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ NA 1 Permit fee attached - - - - - - - - --- - - - ...... - - - _ _ . _ NA 2 Lease number appropriate.... _ _ .. Yes Surface Location lies within FEE-CIRI_(C061505), Portion of Well Passes. Thru ADL0359242; _ 3 Unique well name and number _ _ _ _ _ _ _ _ _ Yes Top. Prod Int & TD lie within ADL0384372. 4 Well located in a defined.pool _ _ _ _ .......... _ _ _ Yes NINILCHIK, BELUGA-TYONEK GAS - 562503,_ governed by CO 701A .. _ 5 Well located proper distance from drilling unit. boundary .. . . . . ............... Yes CO 701A. Rule 3 Well Spacing: 6 Well located proper distance from other wells _ _ _ _ _ _ _ _ _ _ _ _ Yes _ There shall be no. gas well spacing restrictions within the Affected Area,. except:...... 7 Sufficient acreage. available in. drilling unit _ _ _ _ _ _ _ _ _ _ _ _ _ ....... _ Yes A) No gas well shall be drilled or completed less than 1,500 feet from the exterior boundary of 8 If deviated, is wellbore plat. included _ .. .......... . . . . . . Yes the Affected Area unless the owner and landowner is the same on both sides of the line... _ 9 Operator only affected party. .... _ _ _ . ........ . .... . . Yes B). No gas welt shall be drilled or completed less than 1,500feet from an uncommitted tract. 10 Operator has. approprialet bond in force _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ Yes within.the Ninilchik Unit unless the.well and the uncommitted tract both lie within. the same_ _ Appr Date 11 Permit can be issued without conservation order_ _ _ _ _ _ _ _ ____ .... Yes Participating Area. 12 Permit can be issued without administrative. approval _________ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes SFD 3/7/2017 13 Can permit be approved before 15-0ay wait _ _ _ _ _ _ .......... Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in.comments). (For. NA .............. . 15 All wells within 1/4 mile area. of review identified (For service well only) .......... . . . . . NA. 16 Pre -produced injector: duration. of pre -production less than 3 months (For service well only) .. NA, 18 Conductor string_ provided ...... _ _ _ _ _ _ _ ... _ _ Yes 16" conductor set at 120 ft ........ ......... . . . . Engineering 19 Surface casing protects all known USDWs _ _ _ _ _ _ Yes _ _ 7 5B" surface casing to be set at 1500 ft.. and (1380ft TVD)...... _ 20 CMT vol adequate to circulate on conductor. & surf. csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ______ Yes ..... 21 CMT vol adequate to tie-inlong string to surf csg...... .... . . . . . . ..... . . . . Yes 4.5" production string will be cemented to 1100 ft (into surface casing) 22 CMT will coverall known_ productive horizons . . . . . . ......... ...Yes . cement packer completion. Using swell packer as backup.. Needs IA pressure test 23 Casing designs adequate for C, T, B & permafrost........ Yes 24 Adequate tankage or reserve pit _ _ _ _ .... _ _ _ _ _ _ _ _ _ . _ Yes . Rig has steel pits .. All waste to Kenai G & I well. . . . . . . . ............. . 25 If.a re -drill, has a 10-403 for abandonment been approved . . . . . . . . . . . . ......... NA Grassroots well, ,26 Adequate wellbore separation_ proposed. _ _ _ _ . ... - _ _ _ _ Yes _ No issues with close wellbores. 27 If diverter required, does it meet regulations_ _ _ _ _ _ .. ........... NA Diverter waived, Third well on pad with no gas in surface hole. _ 250 ft from last SC point.... Appr Date 28 Drilling fluid program schematic & equip. list.adequate.. . .... . . . . . ........ . . Yes _ Max formation press= 3514_psi _(8.7 ppg EMW) will drill. with 9r10.ppg mud . .... GLS 3/7/2017 29 I30 BOPEs, do they.meet regulation _ _ _ _ _ _ ...... _ . _ - _ . _ _ _ _ _ _ Yes ... Rig 169 has 11 _5000 psi BOPE _ .. BOPS press rating appropriate; test to (put psig in comments)_ _ _ ..... ..... Yes _ .... MASP = 2733 psi. Will test BOPE to 3500 psi .... 31 Choke manifold complies w/API_RP-53 (May 84)...... _ _ _ _ _ _ _ _ _ _ _ __ _ _ _Yes 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ ___ ..... _ Yes ... - _ - CBL requireed after well is finished and. MIT -JA to 2500 psi before perforating. 33 Is presence of H2$ gas probable _ . _ _ _ .. . . . . . . . . . . .........No........ H2S not expected.. Rig has sensors_ and alarms, 34 Mechanical_ condition of wells within AOR verified (For service well only) NA. _ _ ....... _ .. _ _ ........ _ _ .. _ _ _ _ _ _ .................. 35 Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ ______ _ _ _ _ _ _ __ _ _ Yes _ _ _ _ _ H2S is not anticipated based on nearby.wells....... Geology 36 Data. presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ ___________ Yes ....... Expected reservoirpressure is 8.7_ppg EMW; will be drilled using 9.0 to 10.0_ppg mud.. Appr Date 37 Seismic analysis of shallow gas zones ............ . ... . . . _ _ _ _ _NA SFD 3/312017 38 Seabed wndition survey.(if off -shore) _ _ _ _ _ _ _ _______ _ _____ _ _ _ _ _ _ _ _ _ _ _ _ _ NA...................... ...... 39 Contact name/phone for weekly_ progress reports, [exploratory only].... _NA Geologic Engineering Dale Public Date Third well on pad... Diverter waived under 20 AAC 25.035(h)(2) Date: Commissioner: Commissioner: Co r p FS' 31 8//7 a#Xa-8 7 _ -3