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Home My WebLink About216-132Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -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: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -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): 8,866' 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 Pkr; N/A 1,300' MD/1,212' TVD; N/A, N/A 7,773' 5,220' 4,141' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 1CO 701C Same 7,753'4-1/2" ~1246 psi 8,846' 8,540' Length January 22, 2026 N/A 8,846' Perforation Depth MD (ft): See Attached Schematic 2,980psi 6,890psi 120'120' 1,509' Size 120' 1,509' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,360' 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 ADL0384372 / FEE-CIRI 216-132 50-133-20657-00-00 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: No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-006 By Grace Christianson at 4:08 pm, Jan 07, 2026 10-404 BJM 1/14/26 SFD 1/14/2026 Perforate DSR-1/16/26JLC 1/20/2026 01/20/26 Well Prognosis Well Name:Kalotsa 1 API Number:50-133-20657-00-00 Current Status:Online Gas Producer Permit to Drill Number:216-132 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:1613 psi @ 3666 TVD Based on 0.44 psi/ft at deepest proposed perf. Existing perforations are depleted and not at original pressure Max. Potential Surface Pressure:1246 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient:.816 psi/ft using 15.7 ppg EMW FIT at the 7-5/8 surface casing shoe (Average FIT across Paxton/Kalotsa/Dionne Structure) Shallowest Allowable Perf TVD:MPSP/(0.816-0.1) = 1246 psi / 0.716 = 1740 TVD Top of Applicable Gas Pool:1612 MD/1430 TVD (Beluga-Tyonek) Well Status:Online Gas Producer Recent SITP: 230 psi post perforations on 11/21/25 Brief Well Summary Kalotsa 1 was drilled and completed in 2017 and is currently producing from multiple Beluga and Tyonek sands within the BEL 98 T-90 interval. A fill cleanout was performed in 2021, followed by the addition of T7T17 Tyonek sands. In 2022, T5 and T12 sands were added, increasing production to over 2 MM. In 2023, a cap string was installed to stabilize unloading events, which helped flatten the decline rate. Additional perforations were added in February 2025, boosting rates temporarily however, the well ceased flowing after a few months due to fill. Operations restored flow, but rates continued to decline. A fill cleanout was completed in November 2025, followed by perforations in the lower Beluga 98135 interval. An unknown restriction was encountered in the tubing at 5,220 MD during the cleanout preventing intervention below this depth. The purpose of this sundry is to add perforations in the Beluga formation. Notes Regarding Wellbore Condition Inclination o Max inclination = 47.9° at 1512 MD o Max DLS: 5.32° @ 1136 MD Min ID o 2.45 Baker FloGuard Retrievable Patch set at 5144-5179 Restriction o < 1.75 Unknown restriction encountered during CTCO and confirmed with slickline LIBs Recent Tags o 11/20/25 EL perforated multiple intervals from BEL 135 BEL 98 w/ 2-3/4 guns o 11/15/25: SL RIH w/ 2 LIB to 5220. OOH w/ impression of possible parted tubing Pre-Sundry Steps: 1. MIRU SL 2. PT lubricator to 250 psi low / 2,000 psi high 3. D&T to TD to find updated tag. Last tag was 5220 KB in November 2025. LIB showed potential parted tubing Well Prognosis 4. RDMO Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,000 psi high 3. RIH and perforate BEL 60 BEL 135 sands from bottom up: Zone Top MD Btm MD Top TVD Btm TVD Footage BEL 60 3,065' 3,070' 2,435' 2,439' 5' BEL 60 3,074' 3,084' 2,442' 2,449' 10' BEL 60 3,084' 3,099' 2,449' 2,459' 15' BEL 65 3,106' 3,111' 2,464' 2,467' 5' BEL 65 3,146' 3,152' 2,492' 2,496' 6' BEL 65 3,155' 3,160' 2,498' 2,501' 5' BEL 70 3,168' 3,172' 2,507' 2,509' 4' BEL 70 3,176' 3,198' 2,512' 2,527' 22' BEL 72 3,211' 3,216' 2,536' 2,540' 5' BEL 72 3,218' 3,223' 2,541' 2,544' 5' BEL 72 3,230' 3,238' 2,549' 2,555' 8' BEL 73 3,250' 3,258' 2,563' 2,568' 8' BEL73 3,264' 3,268' 2,572' 2,575' 4' BEL 74 3,277' 3,289' 2,581' 2,589' 12' BEL 74 3,308' 3,312' 2,602' 2,605' 4' BEL 74 3,327' 3,331' 2,615' 2,618' 4' BEL 75 3,355' 3,361' 2,635' 2,639' 6' BEL 75 3,373' 3,377' 2,647' 2,650' 4' BEL 78 3,389' 3,393' 2,659' 2,661' 4' BEL 80 3,410' 3,425' 2,673' 2,684' 15' BEL 80 3,427' 3,433' 2,685' 2,690' 6' BEL 81 3,450' 3,454' 2,701' 2,704' 4' BEL 82 3,470' 3,476' 2,715' 2,720' 6' BEL 82 3,488' 3,492' 2,728' 2,731' 4' BEL 88 3,535' 3,540' 2,761' 2,764' 5' BEL 90 3,565' 3,571' 2,782' 2,786' 6' BEL 90 3,572' 3,578' 2,786' 2,790' 6' BEL 90 3,587' 3,592' 2,797' 2,800' 5' BEL 90 3,596' 3,614' 2,803' 2,815' 18' BEL 90 3,636' 3,640' 2,830' 2,833' 4' BEL 91 3,655' 3,659' 2,843' 2,846' 4' BEL 91 3,669' 3,675' 2,853' 2,857' 6' BEL 91 3,683' 3,687' 2,862' 2,865' 4' BEL 91 3,694' 3,698' 2,870' 2,873' 4' BEL 91 3,700' 3,704' 2,874' 2,877' 4' BEL 91 3,706' 3,712' 2,878' 2,882' 6' Well Prognosis BEL 92 3,747' 3,751' 2,906' 2,909' 4' BEL 92 3,758' 3,762' 2,914' 2,917' 4' BEL 92 3,765' 3,770' 2,919' 2,923' 5' BEL 92 3,780' 3,785' 2,930' 2,933' 5' BEL 92 3,788' 3,793' 2,935' 2,939' 5' BEL 92 3,795' 3,801' 2,940' 2,944' 6' BEL 92 3,806' 3,814' 2,948' 2,953' 8' BEL 92 3,824' 3,832' 2,960' 2,966' 8' BEL 93 3,854' 3,859' 2,982' 2,985' 5' BEL 93 3,864' 3,869' 2,989' 2,992' 5' BEL 93 3,878' 3,882' 2,999' 3,002' 4' BEL 94 3,893' 3,899' 3,010' 3,014' 6' BEL 94 3,902' 3,908' 3,016' 3,021' 6' BEL 94 3,917' 3,922' 3,027' 3,031' 5' BEL 95 3,945' 3,950' 3,048' 3,051' 5' BEL 95 3,955' 3,960' 3,055' 3,059' 5' BEL 95 3,971' 3,981' 3,067' 3,075' 10' BEL 97 4,025' 4,029' 3,108' 3,111' 4' BEL 98 4,053' 4,057' 3,129' 3,132' 4' BEL 99B 4,157' 4,162' 3,209' 3,213' 5' BEL 100 4,225' 4,237' 3,263' 3,272' 12' BEL 110 4,305' 4,315' 3,327' 3,336' 10' BEL 115 4,322' 4,326' 3,341' 3,345' 4' BEL 120 4,382' 4,439' 3,391' 3,439' 57' BEL 131 4,450' 4,455' 3,448' 3,453' 5' BEL 131 4,460' 4,466' 3,457' 3,462' 6' BEL 134 4,549' 4,555' 3,533' 3,538' 6' BEL 135 4,670' 4,680' 3,637' 3,646' 10' BEL 135 4,682' 4,701' 3,647' 3,664' 19' BEL 135 4,703' 4,735' 3,666' 3,694' 32' 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 Well Prognosis 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 SRW 12-18-25 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540 / TVD = 7,447 TD = 8,866 / TVD = 7,773 RKB = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84# X-56 Weld 15.01 Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875 Surf 1,509 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958 Surf 8,846 JEWELRY DETAIL No. Depth ID Item 1 1,300 3.958 Baker Swell Packer 2 5,144 5179 2.45 Baker FloGuard Retrievable Patch 3 5,220 <1.75 Unknown Restriction 4 8,540 N/A CIBP 11/17/17 1 16 7-5/8 4-1/2 T140 T9 T90 T83 T81 T43 T17 T14 T8 T6 4 TOC @ ~950 (2/4/17 CBL) T5 T12 T3 T7 T10 2 B98- B135 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status BEL 98 4,066' 4,076' 3,139' 3,147' 10' 11/21/2025 Open BEL 99 4,102' 4,110' 3,167' 3,173' 8' 11/21/2025 Open BEL 100 4,171 4,181 3,220 3,228 10 11/21/2025 Open BEL 100 4,206' 4,211' 3,248' 3,252' 5' 11/21/2025 Open BEL 110 4,271' 4,285' 3,300' 3,311' 14' 11/20/2025 Open BEL 132 4,478' 4,484' 3,472' 3,477' 6' 11/20/2025 Open BEL 132 4,491' 4,497' 3,483' 3,488' 6' 11/20/2025 Open BEL 133 4,504' 4,509' 3,494' 3,499' 5' 11/20/2025 Open BEL 134 4,517' 4,531' 3,506' 3,517' 14' 11/20/2025 Open BEL 134 4,549' 4,555' 3,533' 3,538' 6' 11/20/2025 Open BEL 134 4,560' 4,573' 3,542' 3,553' 13' 11/20/2025 Open BEL 135 4,611' 4,621' 3,586' 3,595' 10' 11/19/2025 Open BEL 135 4,627' 4,635' 3,600' 3,607' 8' 11/19/2025 Open BEL 135 4,641 4,647' 3,612' 3,617' 6' 11/19/2025 Open T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988 4,000 13 6/3/2022 Open T5AL 5,074 5,082 4,003 4,010 8 6/3/2022 Open T5B 5,103 5,121 4,030 4,047 18 6/3/2022 Open T6 5,150 5,175 4,074 4,098 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333 5,353 4,250 4,269 20 4/23/2021 Open T7 5,333 5,353 4,250 4,269 20 3/4/2017 Open T8 5,370 5,387 4,286 4,302 17 4/23/2021 Open T8 5,372 5,392 4,288 4,307 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691 4,707 16 6/3/2022 Open T12L 5,817 5,839 4,725 4,747 22 6/3/2022 Open f 3 Updated by SRW 12-18-25 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PERFORATON DETAIL continued from previous page Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T14 6,067 6,082 4,975 4,990 15 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 4/23/2021 Open T43 6,861 6,870 5,768 5,777 9 3/3/2017 Open T81 7,824 7,833 6,731 6,740 9 3/2/2017 Open T83 7,863 7,879 6,770 6,786 16 3/1/2017 Open T83 7,888 7,896 6,795 6,803 8 3/1/2017 Open T90 8,013 8,033 6,920 6,940 20 3/1/2017 Open T90 8,045 8,065 6,952 6,972 20 3/1/2017 Open T90 8,078 8,110 6,985 7,017 32 2/28/2017 Open T90 8,148 8,168 7,047 7,075 28 2/28/2017 Open T140 8,566 8,596 7,473 7,503 30 2/28/2017 Isolated T140 8,618 8,631 7,525 7,538 13 2/28/2017 Isolated CEMENT DETAILS 7-5/8 Cement Job: 9-7/8 hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2 Cement Job: 6-3/4 hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950 MD. Updated by SRW 12-30-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540 / TVD = 7,447 TD = 8,866 / TVD = 7,773 RKB = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor 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 1,509 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958 Surf 8,846 JEWELRY DETAIL No. Depth ID Item 1 1,300 3.958 Baker Swell Packer 2 5,144 5179 2.45 Baker FloGuard Retrievable Patch 3 5,220 <1.75 Unknown Restriction 4 8,540 N/A CIBP 11/17/17 1 16 7-5/8 4-1/2T140 T9 T90 T83 T81 T43 T17 T14 T8 T6 4 TOC @ ~950 (2/4/17 CBL) T5 T12 T3 T7 T10 2 B98- B135 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status BEL 60 3,065' 3,070' 2,435' 2,439' 5' TBD PROPOSED BEL 60 3,074' 3,084' 2,442' 2,449' 10' TBD PROPOSED BEL 60 3,084' 3,099' 2,449' 2,459' 15' TBD PROPOSED BEL 65 3,106' 3,111' 2,464' 2,467' 5' TBD PROPOSED BEL 65 3,146' 3,152' 2,492' 2,496' 6' TBD PROPOSED BEL 65 3,155' 3,160' 2,498' 2,501' 5' TBD PROPOSED BEL 70 3,168' 3,172' 2,507' 2,509' 4' TBD PROPOSED BEL 70 3,176' 3,198' 2,512' 2,527' 22' TBD PROPOSED BEL 72 3,211' 3,216' 2,536' 2,540' 5' TBD PROPOSED BEL 72 3,218' 3,223' 2,541' 2,544' 5' TBD PROPOSED BEL 72 3,230' 3,238' 2,549' 2,555' 8' TBD PROPOSED BEL 73 3,250' 3,258' 2,563' 2,568' 8' TBD PROPOSED BEL73 3,264' 3,268' 2,572' 2,575' 4' TBD PROPOSED BEL 74 3,277' 3,289' 2,581' 2,589' 12' TBD PROPOSED BEL 74 3,308' 3,312' 2,602' 2,605' 4' TBD PROPOSED BEL 74 3,327' 3,331' 2,615' 2,618' 4' TBD PROPOSED BEL 75 3,355' 3,361' 2,635' 2,639' 6' TBD PROPOSED BEL 75 3,373' 3,377' 2,647' 2,650' 4' TBD PROPOSED BEL 78 3,389' 3,393' 2,659' 2,661' 4' TBD PROPOSED BEL 80 3,410' 3,425' 2,673' 2,684' 15' TBD PROPOSED BEL 80 3,427' 3,433' 2,685' 2,690' 6' TBD PROPOSED BEL 81 3,450' 3,454' 2,701' 2,704' 4' TBD PROPOSED BEL 82 3,470' 3,476' 2,715' 2,720' 6' TBD PROPOSED BEL 82 3,488' 3,492' 2,728' 2,731' 4' TBD PROPOSED BEL 88 3,535' 3,540' 2,761' 2,764' 5' TBD PROPOSED BEL 90 3,565' 3,571' 2,782' 2,786' 6' TBD PROPOSED BEL 90 3,572' 3,578' 2,786' 2,790' 6' TBD PROPOSED BEL 90 3,587' 3,592' 2,797' 2,800' 5' TBD PROPOSED BEL 90 3,596' 3,614' 2,803' 2,815' 18' TBD PROPOSED BEL 90 3,636' 3,640' 2,830' 2,833' 4' TBD PROPOSED BEL 91 3,655' 3,659' 2,843' 2,846' 4' TBD PROPOSED BEL 91 3,669' 3,675' 2,853' 2,857' 6' TBD PROPOSED BEL 91 3,683' 3,687' 2,862' 2,865' 4' TBD PROPOSED BEL 91 3,694' 3,698' 2,870' 2,873' 4' TBD PROPOSED BEL 91 3,700' 3,704' 2,874' 2,877' 4' TBD PROPOSED BEL 91 3,706' 3,712' 2,878' 2,882' 6' TBD PROPOSED BEL 92 3,747' 3,751' 2,906' 2,909' 4' TBD PROPOSED BEL 92 3,758' 3,762' 2,914' 2,917' 4' TBD PROPOSED BEL 92 3,765' 3,770' 2,919' 2,923' 5' TBD PROPOSED BEL 92 3,780' 3,785' 2,930' 2,933' 5' TBD PROPOSED BEL 92 3,788' 3,793' 2,935' 2,939' 5' TBD PROPOSED BEL 92 3,795' 3,801' 2,940' 2,944' 6' TBD PROPOSED BEL 92 3,806' 3,814' 2,948' 2,953' 8' TBD PROPOSED PERFORATON DETAIL continued on following page 3 B60- B135 Updated by SRW 12-30-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PERFORATON DETAIL continued from previous page Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status BEL 92 3,824' 3,832' 2,960' 2,966' 8' TBD PROPOSED BEL 93 3,854' 3,859' 2,982' 2,985' 5' TBD PROPOSED BEL 93 3,864' 3,869' 2,989' 2,992' 5' TBD PROPOSED BEL 93 3,878' 3,882' 2,999' 3,002' 4' TBD PROPOSED BEL 94 3,893' 3,899' 3,010' 3,014' 6' TBD PROPOSED BEL 94 3,902' 3,908' 3,016' 3,021' 6' TBD PROPOSED BEL 94 3,917' 3,922' 3,027' 3,031' 5' TBD PROPOSED BEL 95 3,945' 3,950' 3,048' 3,051' 5' TBD PROPOSED BEL 95 3,955' 3,960' 3,055' 3,059' 5' TBD PROPOSED BEL 95 3,971' 3,981' 3,067' 3,075' 10' TBD PROPOSED BEL 97 4,025' 4,029' 3,108' 3,111' 4' TBD PROPOSED BEL 98 4,053' 4,057' 3,129' 3,132' 4' TBD PROPOSED BEL 98 4,066' 4,076' 3,139' 3,147' 10' 11/21/2025 Open BEL 99 4,102' 4,110' 3,167' 3,173' 8' 11/21/2025 Open BEL 99B 4,157' 4,162' 3,209' 3,213' 5' TBD PROPOSED BEL 100 4,171 4,181 3,220 3,228 10 11/21/2025 Open BEL 100 4,206' 4,211' 3,248' 3,252' 5' 11/21/2025 Open BEL 100 4,225' 4,237' 3,263' 3,272' 12' TBD PROPOSED BEL 110 4,271' 4,285' 3,300' 3,311' 14' 11/20/2025 Open BEL 110 4,305' 4,315' 3,327' 3,336' 10' TBD PROPOSED BEL 115 4,322' 4,326' 3,341' 3,345' 4' TBD PROPOSED BEL 120 4,382' 4,439' 3,391' 3,439' 57' TBD PROPOSED BEL 131 4,450' 4,455' 3,448' 3,453' 5' TBD PROPOSED BEL 131 4,460' 4,466' 3,457' 3,462' 6' TBD PROPOSED BEL 132 4,478' 4,484' 3,472' 3,477' 6' 11/20/2025 Open BEL 132 4,491' 4,497' 3,483' 3,488' 6' 11/20/2025 Open BEL 133 4,504' 4,509' 3,494' 3,499' 5' 11/20/2025 Open BEL 134 4,517' 4,531' 3,506' 3,517' 14' 11/20/2025 Open BEL 134 4,549' 4,555' 3,533' 3,538' 6' 11/20/2025 Open BEL 134 4,560' 4,573' 3,542' 3,553' 13' 11/20/2025 Open BEL 135 4,611' 4,621' 3,586' 3,595' 10' 11/19/2025 Open BEL 135 4,627' 4,635' 3,600' 3,607' 8' 11/19/2025 Open BEL 135 4,641 4,647' 3,612' 3,617' 6' 11/19/2025 Open BEL 135 4,670' 4,680' 3,637' 3,646' 10' TBD PROPOSED BEL 135 4,682' 4,701' 3,647' 3,664' 19' TBD PROPOSED BEL 135 4,703' 4,735' 3,666' 3,694' 32' TBD PROPOSED T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988 4,000 13 6/3/2022 Open T5AL 5,074 5,082 4,003 4,010 8 6/3/2022 Open T5B 5,103 5,121 4,030 4,047 18 6/3/2022 Open T6 5,150 5,175 4,074 4,098 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333 5,353 4,250 4,269 20 4/23/2021 Open T7 5,333 5,353 4,250 4,269 20 3/4/2017 Open CEMENT DETAILS 7-5/8 Cement Job: 9-7/8 hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2 Cement Job: 6-3/4 hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950 MD. Updated by SRW 12-30-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PERFORATON DETAIL continued from previous page Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T8 5,370 5,387 4,286 4,302 17 4/23/2021 Open T8 5,372 5,392 4,288 4,307 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691 4,707 16 6/3/2022 Open T12L 5,817 5,839 4,725 4,747 22 6/3/2022 Open T14 6,067 6,082 4,975 4,990 15 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 4/23/2021 Open T43 6,861 6,870 5,768 5,777 9 3/3/2017 Open T81 7,824 7,833 6,731 6,740 9 3/2/2017 Open T83 7,863 7,879 6,770 6,786 16 3/1/2017 Open T83 7,888 7,896 6,795 6,803 8 3/1/2017 Open T90 8,013 8,033 6,920 6,940 20 3/1/2017 Open T90 8,045 8,065 6,952 6,972 20 3/1/2017 Open T90 8,078 8,110 6,985 7,017 32 2/28/2017 Open T90 8,148 8,168 7,047 7,075 28 2/28/2017 Open T140 8,566 8,596 7,473 7,503 30 2/28/2017 Isolated T140 8,618 8,631 7,525 7,538 13 2/28/2017 Isolated T14 6,067 6,082 4,975 4,990 15 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 4/23/2021 Open T43 6,861 6,870 5,768 5,777 9 3/3/2017 Open STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Scott Warner To:Davies, Stephen F (OGC) Cc:McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC); Starns, Ted C (OGC); Jerry Lau Subject:RE: [EXTERNAL] Kalotsa-1 (PTD 216-132, Sundry 326-006) - Question Date:Tuesday, January 13, 2026 4:38:41 PM Steve, The maximum SITP observed to date is 230 psi. Based on this, the current estimated maximum BHP at the T-90 perforations (7,047 TVD) is approximately 934 psi. We recently encountered an obstruction in the wellbore at around 5,220, with an internal diameter of less than 1.75, which limits any intervention below that depth. However, we believe there is still minor contribution from the sands below. Given the current maximum SITP and a 0.1 psi/ft gradient, the proposed new perforations would represent the highest expected pressure if original reservoir pressure is encountered. Apologies for the delayed response. Scott Warner Kenai Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, January 9, 2026 1:46 PM To: Scott Warner <scott.warner@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: [EXTERNAL] Kalotsa-1 (PTD 216-132, Sundry 326-006) - Question Hello Scott, I'm reviewing Hilcorp's Sundry Application (326-006) for Kalotsa-1 and I have a question. This application requests adding about 700 true vertical feet of perforations atop about 2600 true vertical feet of perforations that are currently open. In the "Maximum Expected BHP" section of the application, you mention "Existing perforations are depleted and not at original pressure." Can you be more specific? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,866' 2,478' (fill) 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 ADL0384372 / FEE-CIRI 216-132 50-133-20657-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,360' Size 120' 1,509' MD See Attached Schematic 2,980psi 6,890psi 120'120' 1,509' November 5, 2025 N/A 8,846' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 1CO 701C Same 7,753'4-1/2" ~1246 psi 8,846' 8,540' Length Baker Swell Pkr; N/A 1,300' MD/1,212' TVD; N/A, N/A 7,773' 8,540' 7,447' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:32 am, Oct 24, 2025 325-664 X CT BOP test to 3000 psi 10-404 BJM 10/30/25 A.Dewhurst 24OCT25 DSR-10/30/25 10 31 25 Well Prognosis Well Name: Kalotsa 1 API Number: 50-133-20657-00-00 Current Status: Shut In Gas Producer Permit to Drill Number: 216-132 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: 1613 psi @ 3666 TVD Based on 0.44 psi/ft at deepest proposed perf. Existing perforations are depleted and not at original pressure Max. Potential Surface Pressure:1246 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .816 psi/ft using 15.7 ppg EMW FIT at the 7-5/8 surface casing shoe (Average FIT across Paxton/Kalotsa/Dionne Structure) Shallowest Allowable Perf TVD: MPSP/(0.816-0.1) = 1613 psi / 0.716 = 2253 TVD Top of Applicable Gas Pool: 1612 MD/1430 TVD (Beluga-Tyonek) Well Status: Online Gas Producer Recent SITP: 390 psi post perforations on 2/16/25 Brief Well Summary Kalotsa 1 is a 2017 new drill completed and producing from multiple Tyonek sands from the T-5 T-90. A 2021 fill cleanout was followed by adding T7 T17 Tyonek sands. In 2022 the T5 & T12 sands were added, boosting production over 2MM. In 2023 a cap string was installed to stabilize the unloading events and had flattened the decline rate. Additional perforations were added in February of 2025 which increased rate but the well stopped flowing after a few months due to fill. Ops was able to get the well back online but rate has had a steep decline since. The purpose of this sundry is to perform a fill cleanout in attempt to restore rate followed by additional perf adds if rate is not restored. Notes Regarding Wellbore Condition Inclination o Max inclination = 47.9° at 1512 MD o Max DLS: 5.32° @ 1136 MD Min ID o 2.45 Baker FloGuard Retrievable Patch set at 5144-5179 Recent Tags o 3/31/25: SL tagged at 1105 KB. Was able to work down to 2478 KB. RDMO Ops was able to get the well back online after this work- current tag depth is unknown o 2/15/25 2/16/25: EL tagged at 5753 MD. Perforated multiple zones from 5610 up to 5247 MD o 2/13/25 2/15/25: SL tagged at 2400. Pumped diesel and able to work tools down to 5,754 RKB after 3 days of bailing/pumping fluid o 7/31/23: SL tagged 5798 KB w/ 2 x 6 DD bailer- 1 cup of sand in bottom of bailer Sat down at the patch but able to work through 15.7 ppg EMW FIT Well Prognosis Pre-Sundry Steps: 1. MIRU SL 2. PT lubricator to 250 psi low / 2,000 psi high 3. D&T to TD to find updated tag. Last tag was 2478 KB in April 2025 prior to Ops successfully onloading the well. 4. RDMO Procedure: 1. MIRU CTU 2. PT BOPE to 250 psi low / 3,000 psi high 3. RIH with coil tubing nozzle/mill and clean out to CIBP at 8540 MD or as deep as possible a. Plan to use 6% KCL/N2 mixture for working fluid 4. RIH and blow well dry with N2 a. Plan to take returns up coil tubing x tubing annulus 5. Hand well over to production to flow test a. Pending results perforations below may not be added b. Lower perforations are assumed to be depleted- if higher pressure is observed while cleaning out, perforations will be re-evaluated 6. MIRU SL (if flow test results are unsuccessful in step 5) 7. PT lubricator to 250 psi low /2,000 psi high 8. D&T in prep for Eline perforations a. Bail if needed b. If bailing is unsuccessful, perform another coil cleanout with 6% KCL/N2 mixture followed by blowing the well dry with N2 9. RDMO CTU and SL 10. MIRU E-line and pressure control equipment 11. PT lubricator to 250 psi low /2,000 psi high 12. RIH and perforate BEL 70 BEL 135 sands from bottom up: 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 BEL 70 ±3,168' ±3,172' ±2,507' ±2,509' ±4' BEL 70 ±3,176' ±3,198' ±2,512' ±2,527' ±22' BEL 72 ±3,211' ±3,216' ±2,536' ±2,540' ±5' BEL 72 ±3,218' ±3,223' ±2,541' ±2,544' ±5' BEL 72 ±3,230' ±3,238' ±2,549' ±2,555' ±8' BEL 73 ±3,250' ±3,258' ±2,563' ±2,568' ±8' BEL73 ±3,264' ±3,268' ±2,572' ±2,575' ±4' BEL 74 ±3,277' ±3,289' ±2,581' ±2,589' ±12' BEL 74 ±3,308' ±3,312' ±2,602' ±2,605' ±4' BEL 74 ±3,327' ±3,331' ±2,615' ±2,618' ±4' BEL 75 ±3,355' ±3,361' ±2,635' ±2,639' ±6' BEL 75 ±3,373' ±3,377' ±2,647' ±2,650' ±4' BEL 78 ±3,389' ±3,393' ±2,659' ±2,661' ±4' BEL 80 ±3,410' ±3,425' ±2,673' ±2,684' ±15' BEL 80 ±3,427' ±3,433' ±2,685' ±2,690' ±6' Well Prognosis BEL 81 ±3,450' ±3,454' ±2,701' ±2,704' ±4' BEL 82 ±3,470' ±3,476' ±2,715' ±2,720' ±6' BEL 82 ±3,488' ±3,492' ±2,728' ±2,731' ±4' BEL 88 ±3,535' ±3,540' ±2,761' ±2,764' ±5' BEL 90 ±3,565' ±3,571' ±2,782' ±2,786' ±6' BEL 90 ±3,572' ±3,578' ±2,786' ±2,790' ±6' BEL 90 ±3,587' ±3,592' ±2,797' ±2,800' ±5' BEL 90 ±3,596' ±3,614' ±2,803' ±2,815' ±18' BEL 90 ±3,636' ±3,640' ±2,830' ±2,833' ±4' BEL 91 ±3,655' ±3,659' ±2,843' ±2,846' ±4' BEL 91 ±3,669' ±3,675' ±2,853' ±2,857' ±6' BEL 91 ±3,683' ±3,687' ±2,862' ±2,865' ±4' BEL 91 ±3,694' ±3,698' ±2,870' ±2,873' ±4' BEL 91 ±3,700' ±3,704' ±2,874' ±2,877' ±4' BEL 91 ±3,706' ±3,712' ±2,878' ±2,882' ±6' BEL 92 ±3,747' ±3,751' ±2,906' ±2,909' ±4' BEL 92 ±3,758' ±3,762' ±2,914' ±2,917' ±4' BEL 92 ±3,765' ±3,770' ±2,919' ±2,923' ±5' BEL 92 ±3,780' ±3,785' ±2,930' ±2,933' ±5' BEL 92 ±3,788' ±3,793' ±2,935' ±2,939' ±5' BEL 92 ±3,795' ±3,801' ±2,940' ±2,944' ±6' BEL 92 ±3,806' ±3,814' ±2,948' ±2,953' ±8' BEL 92 ±3,824' ±3,832' ±2,960' ±2,966' ±8' BEL 93 ±3,854' ±3,859' ±2,982' ±2,985' ±5' BEL 93 ±3,864' ±3,869' ±2,989' ±2,992' ±5' BEL 93 ±3,878' ±3,882' ±2,999' ±3,002' ±4' BEL 94 ±3,893' ±3,899' ±3,010' ±3,014' ±6' BEL 94 ±3,902' ±3,908' ±3,016' ±3,021' ±6' BEL 94 ±3,917' ±3,922' ±3,027' ±3,031' ±5' BEL 95 ±3,945' ±3,950' ±3,048' ±3,051' ±5' BEL 95 ±3,955' ±3,960' ±3,055' ±3,059' ±5' BEL 95 ±3,971' ±3,981' ±3,067' ±3,075' ±10' BEL 97 ±4,025' ±4,029' ±3,108' ±3,111' ±4' BEL 98 ±4,053' ±4,057' ±3,129' ±3,132' ±4' BEL 98 ±4,066' ±4,076' ±3,139' ±3,147' ±10' BEL 99 ±4,102' ±4,110' ±3,167' ±3,173' ±8' BEL 99B ±4,157' ±4,162' ±3,209' ±3,213' ±5' BEL 100 ±4,171' ±4,181' ±3,220' ±3,228' ±10' BEL 100 ±4,206' ±4,211' ±3,248' ±3,252' ±5' BEL 100 ±4,225' ±4,237' ±3,263' ±3,272' ±12' BEL 110 ±4,271' ±4,285' ±3,300' ±3,311' ±14' BEL 110 ±4,305' ±4,315' ±3,327' ±3,336' ±10' BEL 115 ±4,322' ±4,326' ±3,341' ±3,345' ±4' BEL 120 ±4,382' ±4,439' ±3,391' ±3,439' ±57' BEL 131 ±4,450' ±4,455' ±3,448' ±3,453' ±5' Well Prognosis BEL 131 ±4,460' ±4,466' ±3,457' ±3,462' ±6' BEL 132 ±4,478' ±4,484' ±3,472' ±3,477' ±6' BEL 132 ±4,491' ±4,497' ±3,483' ±3,488' ±6' BEL 133 ±4,504' ±4,509' ±3,494' ±3,499' ±5' BEL 134 ±4,517' ±4,531' ±3,506' ±3,517' ±14' BEL 134 ±4,549' ±4,555' ±3,533' ±3,538' ±6' BEL 134 ±4,560' ±4,573' ±3,542' ±3,553' ±13' BEL 135 ±4,611' ±4,621' ±3,586' ±3,595' ±10' BEL 135 ±4,627' ±4,635' ±3,600' ±3,607' ±8' BEL 135 ±4,640' ±4,655' ±3,611' ±3,624' ±15' BEL 135 ±4,670' ±4,680' ±3,637' ±3,646' ±10' BEL 135 ±4,682' ±4,701' ±3,647' ±3,664' ±19' BEL 135 ±4,703' ±4,735' ±3,666' ±3,694' ±32' 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 13. RDMO a. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP diagram 4. Standard Well Procedure N2 Operations Updated by SRW 4-1-25 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540 / TVD = 7,447 TD = 8,866 / TVD = 7,773 RKB = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84# X-56 Weld 15.01 Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875 Surf 1,509 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958 Surf 8,846 JEWELRY DETAIL No. Depth ID Item 1 1,300 3.958 Baker Swell Packer 2 5,144 5179 2.45 Baker FloGuard Retrievable Patch 3 8,540 N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988 4,000 13 6/3/2022 Open T5AL 5,074 5,082 4,003 4,010 8 6/3/2022 Open T5B 5,103 5,121 4,030 4,047 18 6/3/2022 Open T6 5,150 5,175 4,074 4,098 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333 5,353 4,250 4,269 20 4/23/2021 Open T7 5,333 5,353 4,250 4,269 20 3/4/2017 Open T8 5,370 5,387 4,286 4,302 17 4/23/2021 Open T8 5,372 5,392 4,288 4,307 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691 4,707 16 6/3/2022 Open T12L 5,817 5,839 4,725 4,747 22 6/3/2022 Open T14 6,067 6,082 4,975 4,990 15 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 4/23/2021 Open T43 6,861 6,870 5,768 5,777 9 3/3/2017 Open T81 7,824 7,833 6,731 6,740 9 3/2/2017 Open T83 7,863 7,879 6,770 6,786 16 3/1/2017 Open T83 7,888 7,896 6,795 6,803 8 3/1/2017 Open T90 8,013 8,033 6,920 6,940 20 3/1/2017 Open T90 8,045 8,065 6,952 6,972 20 3/1/2017 Open T90 8,078 8,110 6,985 7,017 32 2/28/2017 Open T90 8,148 8,168 7,047 7,075 28 2/28/2017 Open T140 8,566 8,596 7,473 7,503 30 2/28/2017 Isolated T140 8,618 8,631 7,525 7,538 13 2/28/2017 Isolated CEMENT DETAILS 7-5/8 Cement Job: 9-7/8 hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2 Cement Job: 6-3/4 hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950 MD. 1 16 7-5/8 4-1/2 T140 T9 T90 T83 T81 T43 T17 T14 T8 T6 3 TOC @ ~950 (2/4/17 CBL) SL tag at 2478 (4/1/25) T5 T12 T3 T7 T10 2 Updated by SRW 10-22-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540 / TVD = 7,447 TD = 8,866 / TVD = 7,773 RKB = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor Driven to Set Depth 84# X-56 Weld 15.01 Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875 Surf 1,509 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958 Surf 8,846 JEWELRY DETAIL No. Depth ID Item 1 1,300 3.958 Baker Swell Packer 2 5,144 5179 2.45 Baker FloGuard Retrievable Patch 3 8,540 N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status BEL 70 ±3,168' ±3,172' ±2,507' ±2,509' ±4' TBD Proposed BEL 70 ±3,176' ±3,198' ±2,512' ±2,527' ±22' TBD Proposed BEL 72 ±3,211' ±3,216' ±2,536' ±2,540' ±5' TBD Proposed BEL 72 ±3,218' ±3,223' ±2,541' ±2,544' ±5' TBD Proposed BEL 72 ±3,230' ±3,238' ±2,549' ±2,555' ±8' TBD Proposed BEL 73 ±3,250' ±3,258' ±2,563' ±2,568' ±8' TBD Proposed BEL73 ±3,264' ±3,268' ±2,572' ±2,575' ±4' TBD Proposed BEL 74 ±3,277' ±3,289' ±2,581' ±2,589' ±12' TBD Proposed BEL 74 ±3,308' ±3,312' ±2,602' ±2,605' ±4' TBD Proposed BEL 74 ±3,327' ±3,331' ±2,615' ±2,618' ±4' TBD Proposed BEL 75 ±3,355' ±3,361' ±2,635' ±2,639' ±6' TBD Proposed BEL 75 ±3,373' ±3,377' ±2,647' ±2,650' ±4' TBD Proposed BEL 78 ±3,389' ±3,393' ±2,659' ±2,661' ±4' TBD Proposed BEL 80 ±3,410' ±3,425' ±2,673' ±2,684' ±15' TBD Proposed BEL 80 ±3,427' ±3,433' ±2,685' ±2,690' ±6' TBD Proposed BEL 81 ±3,450' ±3,454' ±2,701' ±2,704' ±4' TBD Proposed BEL 82 ±3,470' ±3,476' ±2,715' ±2,720' ±6' TBD Proposed BEL 82 ±3,488' ±3,492' ±2,728' ±2,731' ±4' TBD Proposed BEL 88 ±3,535' ±3,540' ±2,761' ±2,764' ±5' TBD Proposed BEL 90 ±3,565' ±3,571' ±2,782' ±2,786' ±6' TBD Proposed BEL 90 ±3,572' ±3,578' ±2,786' ±2,790' ±6' TBD Proposed BEL 90 ±3,587' ±3,592' ±2,797' ±2,800' ±5' TBD Proposed BEL 90 ±3,596' ±3,614' ±2,803' ±2,815' ±18' TBD Proposed BEL 90 ±3,636' ±3,640' ±2,830' ±2,833' ±4' TBD Proposed BEL 91 ±3,655' ±3,659' ±2,843' ±2,846' ±4' TBD Proposed BEL 91 ±3,669' ±3,675' ±2,853' ±2,857' ±6' TBD Proposed BEL 91 ±3,683' ±3,687' ±2,862' ±2,865' ±4' TBD Proposed BEL 91 ±3,694' ±3,698' ±2,870' ±2,873' ±4' TBD Proposed BEL 91 ±3,700' ±3,704' ±2,874' ±2,877' ±4' TBD Proposed BEL 91 ±3,706' ±3,712' ±2,878' ±2,882' ±6' TBD Proposed BEL 92 ±3,747' ±3,751' ±2,906' ±2,909' ±4' TBD Proposed BEL 92 ±3,758' ±3,762' ±2,914' ±2,917' ±4' TBD Proposed BEL 92 ±3,765' ±3,770' ±2,919' ±2,923' ±5' TBD Proposed BEL 92 ±3,780' ±3,785' ±2,930' ±2,933' ±5' TBD Proposed BEL 92 ±3,788' ±3,793' ±2,935' ±2,939' ±5' TBD Proposed BEL 92 ±3,795' ±3,801' ±2,940' ±2,944' ±6' TBD Proposed BEL 92 ±3,806' ±3,814' ±2,948' ±2,953' ±8' TBD Proposed BEL 92 ±3,824' ±3,832' ±2,960' ±2,966' ±8' TBD Proposed BEL 93 ±3,854' ±3,859' ±2,982' ±2,985' ±5' TBD Proposed CEMENT DETAILS 7-5/8 Cement Job: 9-7/8 hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2 Cement Job: 6-3/4 hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950 MD. 1 16 7-5/8 4-1/2 T140 T9 T90 T83 T81 T43 T17 T14 T8 T6 3 TOC @ ~950 (2/4/17 CBL) T5 T12 T3 T7 T10 2 Updated by SRW 10-22-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status BEL 93 ±3,864' ±3,869' ±2,989' ±2,992' ±5' TBD Proposed BEL 93 ±3,878' ±3,882' ±2,999' ±3,002' ±4' TBD Proposed BEL 94 ±3,893' ±3,899' ±3,010' ±3,014' ±6' TBD Proposed BEL 94 ±3,902' ±3,908' ±3,016' ±3,021' ±6' TBD Proposed BEL 94 ±3,917' ±3,922' ±3,027' ±3,031' ±5' TBD Proposed BEL 95 ±3,945' ±3,950' ±3,048' ±3,051' ±5' TBD Proposed BEL 95 ±3,955' ±3,960' ±3,055' ±3,059' ±5' TBD Proposed BEL 95 ±3,971' ±3,981' ±3,067' ±3,075' ±10' TBD Proposed BEL 97 ±4,025' ±4,029' ±3,108' ±3,111' ±4' TBD Proposed BEL 98 ±4,053' ±4,057' ±3,129' ±3,132' ±4' TBD Proposed BEL 98 ±4,066' ±4,076' ±3,139' ±3,147' ±10' TBD Proposed BEL 99 ±4,102' ±4,110' ±3,167' ±3,173' ±8' TBD Proposed BEL 99B ±4,157' ±4,162' ±3,209' ±3,213' ±5' TBD Proposed BEL 100 ±4,171' ±4,181' ±3,220' ±3,228' ±10' TBD Proposed BEL 100 ±4,206' ±4,211' ±3,248' ±3,252' ±5' TBD Proposed BEL 100 ±4,225' ±4,237' ±3,263' ±3,272' ±12' TBD Proposed BEL 110 ±4,271' ±4,285' ±3,300' ±3,311' ±14' TBD Proposed BEL 110 ±4,305' ±4,315' ±3,327' ±3,336' ±10' TBD Proposed BEL 115 ±4,322' ±4,326' ±3,341' ±3,345' ±4' TBD Proposed BEL 120 ±4,382' ±4,439' ±3,391' ±3,439' ±57' TBD Proposed BEL 131 ±4,450' ±4,455' ±3,448' ±3,453' ±5' TBD Proposed BEL 131 ±4,460' ±4,466' ±3,457' ±3,462' ±6' TBD Proposed BEL 132 ±4,478' ±4,484' ±3,472' ±3,477' ±6' TBD Proposed BEL 132 ±4,491' ±4,497' ±3,483' ±3,488' ±6' TBD Proposed BEL 133 ±4,504' ±4,509' ±3,494' ±3,499' ±5' TBD Proposed BEL 134 ±4,517' ±4,531' ±3,506' ±3,517' ±14' TBD Proposed BEL 134 ±4,549' ±4,555' ±3,533' ±3,538' ±6' TBD Proposed BEL 134 ±4,560' ±4,573' ±3,542' ±3,553' ±13' TBD Proposed BEL 135 ±4,611' ±4,621' ±3,586' ±3,595' ±10' TBD Proposed BEL 135 ±4,627' ±4,635' ±3,600' ±3,607' ±8' TBD Proposed BEL 135 ±4,640' ±4,655' ±3,611' ±3,624' ±15' TBD Proposed BEL 135 ±4,670' ±4,680' ±3,637' ±3,646' ±10' TBD Proposed BEL 135 ±4,682' ±4,701' ±3,647' ±3,664' ±19' TBD Proposed BEL 135 ±4,703' ±4,735' ±3,666' ±3,694' ±32' TBD Proposed T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988 4,000 13 6/3/2022 Open T5AL 5,074 5,082 4,003 4,010 8 6/3/2022 Open T5B 5,103 5,121 4,030 4,047 18 6/3/2022 Open T6 5,150 5,175 4,074 4,098 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333 5,353 4,250 4,269 20 4/23/2021 Open T7 5,333 5,353 4,250 4,269 20 3/4/2017 Open T8 5,370 5,387 4,286 4,302 17 4/23/2021 Open T8 5,372 5,392 4,288 4,307 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691 4,707 16 6/3/2022 Open T12L 5,817 5,839 4,725 4,747 22 6/3/2022 Open Updated by SRW 10-22-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T14 6,067 6,082 4,975 4,990 15 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 3/2/2017 Open T17 6,306 6,326 5,213 5,233 20 4/23/2021 Open T43 6,861 6,870 5,768 5,777 9 3/3/2017 Open T81 7,824 7,833 6,731 6,740 9 3/2/2017 Open T83 7,863 7,879 6,770 6,786 16 3/1/2017 Open T83 7,888 7,896 6,795 6,803 8 3/1/2017 Open T90 8,013 8,033 6,920 6,940 20 3/1/2017 Open T90 8,045 8,065 6,952 6,972 20 3/1/2017 Open T90 8,078 8,110 6,985 7,017 32 2/28/2017 Open T90 8,148 8,168 7,047 7,075 28 2/28/2017 Open T140 8,566 8,596 7,473 7,503 30 2/28/2017 Isolated T140 8,618 8,631 7,525 7,538 13 2/28/2017 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, October 27, 2025 3:57 PM To:McLellan, Bryan J (OGC) Cc:Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Starns, Ted C (OGC) Subject:RE: [EXTERNAL] Kalotsa 1 (PTD 216-132) perf sundry Attachments:RE: [EXTERNAL] RE: Kalotsa 2 AOGCC 10-403 325-278 PTD 216-155 Approved 05-13-25 Bryan, The highest SITP we saw a er the last perfora ng campaign in February 2025 was 383 psi. As for the FIT, I have a ached the email from May 2025 that addresses this issue where we agreed a 15.7 ppg FIT across the structure was a conserva ve es mate. Let me know if you need anything further. 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, October 27, 2025 3:41 PM To: Scott Warner scott.warner@hilcorp.com Cc: Davies, Stephen F (OGC) steve.davies@alaska.gov Dewhurst, Andrew D (OGC) andrew.dewhurst@alaska.gov Starns, Ted C (OGC) ted.starns@alaska.gov Subject: E TERNAL Kalotsa 1 (PTD 216-132) perf sundry Scott, Please provide evidence that the existing perfs are depleted and the MPSP should be based on anticipated pressure of new perfs. Even somewhat depleted perfs might yield a higher MPSP since the deepest open perfs are much deeper than the deepest proposed perf. Also note that in Feb of this year, Hilcorp provided an average Kalotsa well FIT/LOT of 13.73 ppg for Kalotsa 10 because the exceptionally high FITs were excluded from the average. In the current sundry, 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 you proposed an average LOT value of 15.7 ppg. Please provide the data used and logic for using this higher average. Im inclined to use the FIT from Kalotsa 1 as the basis for shallowest perf since theres variation across wells and this errs on the side of caution. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,866'2,478' (Fill) 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 Other: CTCO, N2 Baker Swell Packer & N/A 1,300 (MD) / 1,212 (TVD) & N/A 7,773'8,540'7,447' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 1CO 701C Same 7,753'4-1/2" ~2395psi 8,846' 8,540' Size April 4, 2025 N/A 8,846' Perforation Depth MD (ft): See Attached Schematic See Attached Schematic 2,980psi 6,890psi 120'120' 1,509' 120' 1,509' MDLength Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,360' 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 ADL0384372 / FEE-CIRI 216-132 50-133-20657-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner 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 By Grace Christianson at 3:22 pm, Apr 01, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.04.01 14:46:55 - 08'00' Noel Nocas (4361) 325-193 10-404 combined w/ sundry 325-010 BJM 4/3/25 DSR-4/2/25 CT BOP test to 3500 psi. X *&:SFD 4/4/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.04 14:05:11 -08'00'04/04/25 RBDMS JSB 040825 Well Prognosis Well Name: Kalotsa 1 API Number: 50-133-20657-00-00 Current Status: Shut In Gas Producer Permit to Drill Number: 216-132 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: 3100 psi @ 7047’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2395 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.74 psi/ft using 14.3 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.74-0.1) = 2395 psi / 0.64 = 3742‘ TVD Top of Applicable Gas Pool: 1612’ MD/1430’ TVD (Beluga-Tyonek) Well Status: Offline Gas Producer Brief Well Summary Kalotsa 1 is a 2017 new drill completed and producing from multiple Tyonek sands from the T-5 – T-90. A 2021 fill cleanout was followed by adding T7 – T17 Tyonek sands. In 2022 the T5 & T12 sands were added, once again boosting production over 2MM. Fill issues have persisted with the current top of fill over the T12 perfs at 5800’ based on last slickline tag. In 2023 a cap string was installed to stabilize the unloading events and has flattened the decline rate. Additional perforations were added in February of 2025 which increased rate but the well has since stopped flowing due to fill in the wellbore. The purpose of this sundry is to return the well to production by performing a cleanout with coil tubing. Notes Regarding Wellbore Condition x Inclination o Max inclination = 47.9° at 1512’ MD o Max DLS: 5.32° @ 1136’ MD x Min ID o 2.45” – Baker FloGuard Retrievable Patch set at 5144’-5179’ x Recent Tags o 3/31/25: SL tagged at 1105’ KB. o 2/13/25 – 2/15/25: SL tagged at 2400’. Pumped diesel and able to work tools down to 5,754 RKB after 3 days of bailing/pumping fluid. o 7/31/23: SL tagged 5798’ KB w/ 2” x 6’ DD bailer- 1 cup of sand in bottom of bailer Sat down at the patch but able to work through Procedure: 1. MIRU CTU 2. PT BOPE to 250 psi low / 3,000 psi high 3. RIH with coil tubing nozzle or mill and clean out to CIBP at 8540’ MD or as deep as possible a. Plan to use 6% KCL/N2 mixture for working fluid 4. RIH and blow well dry with N2 Well Prognosis a. Plan to take returns up coil tubing x tubing annulus 5. RDMO CTU Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP diagram 4. Standard Well Procedure – N2 Operations Updated by SRW 4-1-25 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988’ 4,000’ 13’ 6/3/2022 Open T5AL 5,074 5,082 4,003’ 4,010’ 8’ 6/3/2022 Open T5B 5,103 5,121 4,030’ 4,047’ 18’ 6/3/2022 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/2021 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/2017 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/2021 Open T8 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691’ 4,707’ 16’ 6/3/2022 Open T12L 5,817 5,839 4,725’ 4,747’ 22’ 6/3/2022 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/2021 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/2017 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/2017 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/2017 Open T83 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/2017 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/2017 Open T90 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/2017 Open T90 8,078’ 8,110 6,985’ 7,017’ 32 2/28/2017 Open T90 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/2017 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/2017 Isolated T140 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/2017 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T9 T90 T83 T81 T43 T17 T14 T8 T6 3 TOC @ ~950’ (2/4/17 CBL) SL tag at 2478’ (4/1/25) T5 T12 T3 T7 T10 2 Updated by SRW 4-1-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988’ 4,000’ 13’ 6/3/2022 Open T5AL 5,074 5,082 4,003’ 4,010’ 8’ 6/3/2022 Open T5B 5,103 5,121 4,030’ 4,047’ 18’ 6/3/2022 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/2021 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/2017 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/2021 Open T8 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691’ 4,707’ 16’ 6/3/2022 Open T12L 5,817 5,839 4,725’ 4,747’ 22’ 6/3/2022 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/2021 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/2017 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/2017 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/2017 Open T83 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/2017 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/2017 Open T90 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/2017 Open T90 8,078’ 8,110 6,985’ 7,017’ 32 2/28/2017 Open T90 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/2017 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/2017 Isolated T140 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/2017 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T9 T90 T83 T81 T43 T17 T14 T8 T6 3 TOC @ ~950’ (2/4/17 CBL) T5 T12 T3 T7 T10 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. 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: Pull Cap String Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,866 feet 8,540 feet true vertical 7,773 feet 6,342 (Fill)feet Effective Depth measured 8,540 feet 1,300 feet true vertical 7,447 feet 1,212 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A 1,300 MD Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr 1,212 TVD SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 7,500psi 2,980psi 6,890psi 8,430psi 1,509'1,360' Burst Collapse 1,410psi 4,790psi Production Liner 8,846' Casing Structural 7,753'8,846' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,509' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-132 50-133-20657-00-00 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: ADL0384372 / FEE-CIRI Ninilchik / Beluga-Tyonek Gas Ninilchik Unit Kalotsa 1 Plugs Junk measured Length 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 51 Size 120' 0 542200 0 380 59 Scott Warner, Operations Engineer 324-010 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 677 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 p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:24 am, Mar 17, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.03.14 16:40:56 - 08'00' Noel Nocas (4361) DSR-3/25/25 325-010 JSB RBDMS JSB 032425 BJM 5/2/25 Page 1/1 Well Name: NINU Kalotsa 01 Report Printed: 3/5/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20657-00-00 Field Name:Ninilchik State/Province:Alaska Permit to Drill (PTD) #:216-132 Sundry #:325-010 Rig Name/No: Jobs Actual Start Date:2/6/2025 End Date: Report Number 1 Report Start Date 2/12/2025 Report End Date 2/13/2025 Last 24hr Summary MIRU Capillary string truck. Load spool and stab injector head with cap string initially set at 5000' 1800 lbs up weight. Remove hanger and back out lock down screws. PIck jp clean at 1800-1900 lbs. PUll 5000' of 3/8 SS capillary tubing to surface. WHP 40 psi. ALl tubing and foot valve recovered. Rig down capstring truck and park on edge of pad. New electronic counter had some issues with depth K factor adjustment. Report Number 2 Report Start Date 2/13/2025 Report End Date 2/13/2025 Last 24hr Summary Attempt to drift tubing - having issues w/ thick soap pump approximately 200 gal. diesel pumped PTW/PJSM. FTP 40 psi. RU Pollard Slickline. PT lubricator 250 psi low / 3000 psi high - Good. RIH w/ 3.75" GR and tag @ 2,400' RKB falling slow. OOH- tools covered in thick soap. Pump 20 gals methanol and RIH w/ 2" x 20' dummy gun and tag @ 5,064' RKB. Pump 50 gals diesel and RIH w/ 2" bailer and set down @ 2,450'. RIH w/ 2" x 10' dummy gun plus added weight bar and set down @ 3,700'. Shut in well and pump 50 gals diesel and RIH w/ same, set down @ 3,317' and WT 3,795'. POOH, pump 50 gals diesel and RIH w/ same to 5,125'. POOH and pump 50 gals diesel. Leave shut in to soak for night. Secure well and SDFN. Report Number 3 Report Start Date 2/14/2025 Report End Date 2/14/2025 Last 24hr Summary Drift tubing w/ 3.75'' g-ring to 5140'kb 2''x20' dummy guns to 5752'kb - did sit down @ patch 5140' fell thru fairly easy ( picked up 5' RIH @ different speeds & fell thru did not see patch pooh PTW/PJSM. SITP 185 psi. RU Pollard Slickline. RIH w/ 2" x 10' dummy gun plus added weight bar and tag @ 5,752' RKB. RIH w/ 3.75" GR and tag top of casing patch @ 5,140' RKB. RIH w/ 2" x 20' dummy gun and tag @ 5,754' RKB. Secure well, RD Pollard. Report Number 4 Report Start Date 2/15/2025 Report End Date 2/15/2025 Last 24hr Summary PTW/PJSM. SITP 195 psi. MIRU YJ Eline. PT lubricator to 250 psi low / 3000 psi high - good test. RIH w/ GPT and tag @ 5,753'- fluid level @ 5,395'. RIH w/ 10'x6'x10' 2" 6SPF 60DEG guns on switch and perf TY_10B Lower (5,600’ – 5,610’), TY_10B Upper (5,592’ – 5,598’), and TY_10 (5,511’ – 5,521’). RIH w/ 16'x6' 2" 6SPF 60DEG guns on switch and perf TY_9A (5,464’ – 5,480’) and TY_8 Lower (5,399’ – 5,405’). RIH w/ 6'x20' 2" 6SPF 60DEG guns on switch and perf TY_8 Upper (5,389’ – 5,395’) and TY_7 Lower (5,283’ – 5,303’). RIH w/ 10'x6'x6' 2" 6SPF 60DEG guns on switch and perf TY_7 Middle (5,273’ – 5,283’), TY_7 Upper (5,263’ – 5,269’), and TY_6 Lower (5,247’ – 5,253’). Secure well and flow test. Report Number 5 Report Start Date 2/16/2025 Report End Date 2/16/2025 Last 24hr Summary PTW/PJSM. SITP 330 psi. MIRU YJ Eline. RIH w/ 8'x6'x6' 2" 6SPF 60DEG guns on switch and perf TY_6 Middle (5,208’ – 5,216’), TY_6 Upper (5,183’ – 5,189’), and TY_5 (5,021’ – 5,027’). RIH w/ 27' x 2" 6SPF 60DEG guns and perf TY_3 Lower (4,931’ – 4,958’). RIH w/ 6'x10' 2" 6SPF 60DEG guns on switch and perf TY_3 Middle (4,907’ – 4,913’) and TY_3 Upper (4,885’ – 4,895’). RIH w/ 14' x 2" 6SPF 60DEG guns and perf TY_3 Upper (4,871’ – 4,885’). Secure well, RD YJ E- line, and hand off to production. Report Number 6 Report Start Date 2/17/2025 Report End Date 2/17/2025 Last 24hr Summary PTW/PJSM. Well flowing 2.3MM @ 60 psi. RU YJ Eline. RIH w/ 1 11/16" GPT and tag @ 5,565'. Found fluid level @ ~5,400'. Secure well, RDMO YJ E-line. Updated by DM 03-07-25 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988’ 4,000’ 13’ 6/3/2022 Open T5AL 5,074 5,082 4,003’ 4,010’ 8’ 6/3/2022 Open T5B 5,103 5,121 4,030’ 4,047’ 18’ 6/3/2022 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/2021 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/2017 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/2021 Open T8 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691’ 4,707’ 16’ 6/3/2022 Open T12L 5,817 5,839 4,725’ 4,747’ 22’ 6/3/2022 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/2021 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/2017 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/2017 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/2017 Open T83 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/2017 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/2017 Open T90 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/2017 Open T90 8,078’ 8,110 6,985’ 7,017’ 32 2/28/2017 Open T90 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/2017 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/2017 Isolated T140 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/2017 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T9 T90 T83 T81 T43 T17 T14 T8 T6 2 TOC @ ~950’ (2/4/17 CBL) SL tag at 5,754’ (2/14/25) T5 T12 T3 T7 T10 Superseded Updated by DM 03-28-25 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top MD Btm MD Top TVD Btm TVD Ft Perf Date Status T3 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3U 4,871' 4,895' 3,814' 3,836' 24' 2/16/2025 Open T3M 4,907' 4,913' 3,847' 3,853' 6' 2/16/2025 Open T3L 4,931' 4,958' 3,869' 3,894' 27' 2/16/2025 Open T5 5,021' 5,027' 3,953' 3,959' 6' 2/16/2025 Open T5AU 5,058 5,071 3,988’ 4,000’ 13’ 6/3/2022 Open T5AL 5,074 5,082 4,003’ 4,010’ 8’ 6/3/2022 Open T5B 5,103 5,121 4,030’ 4,047’ 18’ 6/3/2022 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/2017 Patched 3/27/21 T6U 5,183' 5,189' 4,106' 4,111' 6' 2/16/2025 Open T6M 5,208' 5,216' 4,130' 4,137' 8' 2/16/2025 Open T6L 5,247' 5,253' 4,167' 4,173' 6' 2/16/2025 Open T7U 5,263' 5,269' 4,182' 4,188' 6' 2/16/2025 Open T7L 5,273' 5,303' 4,192' 4,221' 30' 2/16/2025 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/2021 Open T7 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/2017 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/2021 Open T8 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/2017 Open T8U 5,389' 5,395' 4,304' 4,310' 6' 2/16/2025 Open T8L 5,399' 5,405' 4,314' 4,320' 6' 2/16/2025 Open T9A 5,464' 5,480' 4,377' 4,393' 16' 2/16/2025 Open T10 5,511' 5,521' 4,423' 4,433' 10' 2/16/2025 Open T10BU 5,592' 5,598' 4,503' 4,508' 6' 2/16/2025 Open T10BL 5,600' 5,610' 4,510' 4,520' 10' 2/16/2025 Open T12U 5,783 5,799 4,691’ 4,707’ 16’ 6/3/2022 Open T12L 5,817 5,839 4,725’ 4,747’ 22’ 6/3/2022 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/2017 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/2021 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/2017 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/2017 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/2017 Open T83 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/2017 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/2017 Open T90 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/2017 Open T90 8,078’ 8,110 6,985’ 7,017’ 32 2/28/2017 Open T90 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/2017 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/2017 Isolated T140 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/2017 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 1 16” 7-5/8” 7-5/8” 4-1/2” 4-1/2” T140 T140 T9 T8 T90 T90 T83 T83 T81 T81 T43 T43 T17 T17 T14 T14 T8 T7 T6 T6 3 3 TOC @ ~950’ (2/4/17 CBL) PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T-5AU 5,058 5,071 3,988’ 4,000’ 13’ 06/03/22 Open T-5AL 5,074 5,082 4,003’ 4,010’ 8’ 06/03/22 Open T-5B 5,103 5,121 4,030’ 4,047’ 18’ 06/03/22 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T-12U 5,783 5,799 4,691’ 4,707’ 16’ 06/03/22 Open T-12L 5,817 5,839 4,725’ 4,747’ 22’ 06/03/22 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated TOC @ ~950’ (2/4/17 CBL) SL tag at 5,754’ (2/14/25) SL tag at 63412’ w 2” DDB (5-19-22) T5 T5 T12 T12 T3 T5 T5 T7 T6 T10 T8 2 2 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,866'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 Other: Pull / Install Cap String Baker Swell Packer & N/A 1,300 (MD) / 1,212 (TVD) & N/A 7,773' 8,540' 7,447' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 1CO 701C Same 7,753'4-1/2" 2,395 8,846' 8,540' January 24, 2025 N/A 8,846' Perforation Depth MD (ft): See Attached Schematic See Attached Schematic 2,980psi 6,890psi 120'120' 1,509' Size 120' 1,509' MDLength Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,360' 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 ADL0384372 / FEE-CIRI 216-132 50-133-20657-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner 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: No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:37 pm, Jan 10, 2025 325-010 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.01.10 12:48:25 - 09'00' Noel Nocas (4361) DSR-1/16/25SFD 1/16/2025 10-404 BJM 1/23/25 CT BOP test to 3000 psi (contingency) X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.23 15:58:20 -09'00'01/23/25 RBDMS JSB 012425 Well Prognosis Well Name:Kalotsa 1 API Number:50-133-20657-00-00 Current Status:Producing Gas Well Permit to Drill Number:216-132 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:3100 psi @ 7047’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:2395 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient:0.74 psi/ft using 14.3 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD:MPSP/(0.74-0.1) = 2395 psi / 0.64 = 3742‘ TVD Top of Applicable Gas Pool:1612’ MD/1430’ TVD (Beluga-Tyonek) Well Status:Online Gas producer – 676 mscfd, 4 bwpd, 40 psi FTP Brief Well Summary Kalotsa 1 is a 2017 new drill completed and producing from multiple Tyonek sands from the T-5 – T-90. A 2021 fill cleanout was followed by adding T7 – T17 Tyonek sands. In 2022 the T5 & T12 sands were added, once again boosting production over 2MM. Fill issues have persisted with the current top of fill over the T12 perfs at 5800’ based on last slickline tag. In 2023 a cap string was installed to stabilize the unloading events and has flattened the decline rate. The purpose of this sundry is to increase rate by perforating additional Tyonek sands. Notes Regarding Wellbore Condition x Inclination o Max inclination = 47.9° at 1512’ MD o Max DLS: 5.32° @ 1136’ MD x Min ID o 2.45” – Baker FloGuard Retrievable Patch set at 5144’-5179’ x Recent Tags o 7/31/23: SL tagged 5798’ KB w/ 2” x 6’ DD bailer- 1 cup of sand in bottom of bailer Sat down at the patch but able to work through Pre-Sundry Steps: 1. MIRU Cap string truck 2. Pull 3/8” cap string 3. RD cap string truck 4. RU slickline 5. PT lubricator to 250 psi low/ 3,000 psi high 6. D&T to TD to find updated tag. Last SL tag was 5798’ KB in July 2023 a. Previous tag in May 2022 was 6342’ KB b. Drifted through patch w/ 2” x 20’ dummy guns. Sat down in patch 50% of time but was able to work through and had no issues coming up through the patch 7. Pull Baker FloGaurd retrievable patch from 5144’-5179’ a. Need an updated tag prior to patch being pulled to confirm T-6 is not contributing sand 8. RDMO slickline Well Prognosis 9. Ops to flow test well post patch pull to verify rates. No rate changes were seen when the patch was set in 2021 and fill has continued to accumulate in the wellbore Contingency: 1. RU slickline 2. PT lubricator to 250 psi low/ 3,000 psi high 3. D&T to TD to find updated tag. a.If tag depth has changed since patch pull and/or gas rate has fallen off, rig up eline and re-run patch across T-6 perforations from 5144’-5179’ or rig up coil tubing and perform a fill cleanout down to the CIBP at 8540’ or as deep as possible. 4. RDMO slickline Eline Contingency: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /3,000 psi high 3. RIH and set patch across T-6 perforations 4. Proceed with perf procedure below using 2” guns in place of 2-7/8” now that the patch is back in place 5. RDMO Coil Contingency: 1. MIRU CTU 2. PT BOPE to 2050 psi low / 3,000 psi high 3. RIH with coil tubing nozzle or mill and clean out as deep as possible to CIBP at 8540’ MD 4. RIH and reverse out fluid with nitrogen, trap 1200 psi on the wellbore a. Verify pressure with OE/RE prior to RIH 5. RDMO CTU Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /3,000 psi high 3. RIH and perforate TY 3 – TY 53 sands from bottom up with 2-7/8” 60 deg phased perf guns: 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 Sand Top MD Btm MD Top TVD Btm TVD Interval TY_3 ±4,871' ±4,895' ±3,814' ±3,836' ±24' TY_3 ±4,907' ±4,913' ±3,847' ±3,853' ±6' TY_3 ±4,931' ±4,958' ±3,869' ±3,894' ±27' TY_5 ±5,021' ±5,027' ±3,953' ±3,959' ±6' TY_6 ±5,183' ±5,189' ±4,106' ±4,111' ±6' TY_6 ±5,208' ±5,216' ±4,130' ±4,137' ±8' TY_6 ±5,247' ±5,253' ±4,167' ±4,173' ±6' TY_7 ±5,263' ±5,269' ±4,182' ±4,188' ±6' TY_7 ±5,273' ±5,303' ±4,192' ±4,221' ±30' TY_8 ±5,389' ±5,395' ±4,304' ±4,310' ±6' TY_8 ±5,399' ±5,405' ±4,314' ±4,320' ±6' Well Prognosis TY_9A ±5,464' ±5,480' ±4,377' ±4,393' ±16' TY_10 ±5,511' ±5,521' ±4,423' ±4,433' ±10' TY_10B ±5,592' ±5,598' ±4,503' ±4,508' ±6' TY_10B ±5,600' ±5,610' ±4,510' ±4,520' ±10' Perforations below this point may not be accessible due to fill T-15 ±6,155' ±6,169' ±5,063' ±5,077' ±14' T-16 ±6,208' ±6,218' ±5,116' ±5,126' ±10' T-17 ±6,295' ±6,301' ±5,202' ±5,208' ±6' T-17 ±6,328' ±6,342' ±5,235' ±5,249' ±14' T-18 ±6,424' ±6,454' ±5,331' ±5,361' ±30' T-18 ±6,459' ±6,465' ±5,366' ±5,372' ±6' T-18 ±6,472' ±6,486' ±5,379' ±5,393' ±14' T-18 ±6,501' ±6,507' ±5,408' ±5,414' ±6' T-37 ±6,709' ±6,719' ±5,616' ±5,626' ±10' T-43 ±6,881' ±6,887' ±5,788' ±5,794' ±6' T-53 ±7,360' ±7,370' ±6,267' ±6,277' ±10' T-53 ±7,374' ±7,388' ±6,281' ±6,295' ±14' 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, re- run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP diagram 4. Standard Well Procedure – N2 Operations Updated by SRW 1-10-25 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T-5AU 5,058 5,071 3,988’ 4,000’ 13’ 06/03/22 Open T-5AL 5,074 5,082 4,003’ 4,010’ 8’ 06/03/22 Open T-5B 5,103 5,121 4,030’ 4,047’ 18’ 06/03/22 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T-12U 5,783 5,799 4,691’ 4,707’ 16’ 06/03/22 Open T-12L 5,817 5,839 4,725’ 4,747’ 22’ 06/03/22 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 TOC @ ~950’ (2/4/17 CBL) 2 SL tag at 5798’ w 2” DDB (7-31-23) T5 T12 3//8” Capillary String Installed 08/04/23 Top Bottom MD 0’ 5,000’ Updated by SRW 1-9-25 PROPOSED Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T3 – T53 ±4,871’ ±7,388’ ±3,814’ ±6,295’ Proposed TBD T-5AU 5,058 5,071 3,988’ 4,000’ 13’ 06/03/22 Open T-5AL 5,074 5,082 4,003’ 4,010’ 8’ 06/03/22 Open T-5B 5,103 5,121 4,030’ 4,047’ 18’ 06/03/22 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T-12U 5,783 5,799 4,691’ 4,707’ 16’ 06/03/22 Open T-12L 5,817 5,839 4,725’ 4,747’ 22’ 06/03/22 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 TOC @ ~950’ (2/4/17 CBL) SL tag at 5798’ w 2” DDB (7-31-23) T5 T12 T3 T53 T3- T53 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull Cap String, CTCO, N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,866'7,801' 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 jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0384372 / FEE-CIRI 216-132 50-133-20657-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,360' Size 120' 1,509' MD See Attached Schematic 2,980psi 6,890psi 120'120' 1,509' December 25, 2023 N/A 8,846' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 1CO 701C Same 7,753'4-1/2" ~2396 psi 8,846' 8,540' Length Baker Swell Packer & N/A 1,300 (MD) / 1,212 (TVD) & N/A 7,773'8,450'7,447' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s 66 t 2 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 7:43 am, Dec 13, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.12.12 16:12:56 - 09'00' Noel Nocas (4361) 323-665 SFD 12/13/2023 DSR-12/14/23 Perforate Fill Cleanout - DSR BJM 12/21/23 10-404 CT BOP test to 2500 psi X *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.21 11:06:38 -09'00'12/21/23 RBDMS 122623 JSB Well Prognosis Well Name:Kalotsa 1 API Number:50-133-20657-00-00 Current Status:Gas Producer Permit to Drill Number:216-132 First Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (M) Second Call Engineer:Chad Helgeson (907) 777-8420 (O)(907) 229-4824 (M) Maximum Expected BHP: ~ 3100 psi @ 7047’ TVD (0.44 psi/ft gradient to bottom open perf) Max. Potential Surface Pressure: ~ 2396 psi (Max expected BHP minus gas to surface) Well Status: Online Gas Producer Last well test: 1300 mcfd @ 60 psi Brief Well Summary Kalotsa 1 is a 2017 new drill completed and producing from multiple Tyonek sands from the T-5 – T-90. A 2021 fill cleanout was followed by adding T7 – T17 Tyonek sands. In 2022 the T5 & T12 sands were added, once again boosting production over 2MM. Fill issues have persisted with the current top of fill over the T12 perfs at 5800’. In 2023 a cap string was installed to stabilize the unloading events and has flattened the decline rate. The objective of this sundry is to increase production through a fill cleanout & additional Tyonek perforations. History: March 2021 Coil fill cleanout to 7200’ E-line set Baker retrievable patch over T6 at 5144-5178’ Coil fill cleanout to 7801’, stop due to hard fill, blow down, perforate T6, T7, T17 Pre-Sundry Steps: 1. Pull cap string 2. RU slickline, PT lubricator to 2500 psi pull retrievable from patch over the T-6 perforations Sundry Steps: 1. Review approved COAs 2. MIRU coil tubing, proved 24 hrs notice to AOGCC, BOP test to 2500 psi 3. RIH cleanout nozzle, use nitrogen to assist in fill cleanout as deep as possible 4. Flow test well 5. Perforate Tyonek sands within the below interval from the bottom up: Top Tyonek 3 4872’ MD 3815’ TVD Bottom Tyonek 53 7389’ MD 6296’ TVD a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. If necessary use nitrogen to pressure up well during perforating 6. Return to production Attachments: 1. Actual Schematic 2. Proposed Schematic 7389’ MD 6296’ TVD 4872’ MD 3815’ TVD Well Prognosis 3. Coil Tubing BOP diagram 4. Nitrogen SOP Updated by DMA 06-21-23 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T-5AU 5,058 5,071 3,988’ 4,000’ 13’ 06/03/22 Open T-5AL 5,074 5,082 4,003’ 4,010’ 8’ 06/03/22 Open T-5B 5,103 5,121 4,030’ 4,047’ 18’ 06/03/22 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T-12U 5,783 5,799 4,691’ 4,707’ 16’ 06/03/22 Open T-12L 5,817 5,839 4,725’ 4,747’ 22’ 06/03/22 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 TOC @ ~950’ (2/4/17 CBL) 2 SL tag at 6342’ w 2” DDB (5-19-22) T5 T12 3//8” Capillary String Installed 08/04/23 Top Bottom MD 0’ 5,000’ Updated by DMA 12-11-23 PROPOSED Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T-3 ±4,872’ ±7,389’ ±3,815’ ±6,296’ Proposed TBD T-5AU 5,058 5,071 3,988’ 4,000’ 13’ 06/03/22 Open T-5AL 5,074 5,082 4,003’ 4,010’ 8’ 06/03/22 Open T-5B 5,103 5,121 4,030’ 4,047’ 18’ 06/03/22 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T-12U 5,783 5,799 4,691’ 4,707’ 16’ 06/03/22 Open T-12L 5,817 5,839 4,725’ 4,747’ 22’ 06/03/22 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 TOC @ ~950’ (2/4/17 CBL) 2 SL tag at 6342’ w 2” DDB (5-19-22) T5 T12 T5 T5 T5- T53 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. 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: Install Cap String Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,866 feet 8,540 feet true vertical 7,773 feet 6,342 (Fill)feet Effective Depth measured 8,540 feet 1,300 feet true vertical 7,447 feet 1,212 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A 1,300 MD Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr 1,212 TVD SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Jake Flora, Operations Engineer 323-354 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1427 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 jake.flora@hilcorp.com 907-777-8442 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 52 Size 120' 0 531316 0 553 60 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-132 50-133-20657-00-00 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: ADL0384372 / FEE-CIRI Ninilchik / Beluga-Tyonek Gas Ninilchik Unit Kalotsa 1 Plugs Junk measured Length Production Liner 8,846' Casing Structural 7,753'8,846' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,509' 7,500psi 2,980psi 6,890psi 8,430psi 1,509'1,360' 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 Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.08.29 16:24:10 - 08'00' Noel Nocas (4361) By Grace Christianson at 8:42 am, Aug 30, 2023 DSR-8/31/23 RBDMS JSB 083123 Rig Start Date End Date Cap String 8/3/23 8/3/23 08/03/2023 - Thursday MIRU cap string truck and new 3/8"x 10,000' string. Make up 1" OD x 13" foot valve. Set at 2300 psi. Stab on well. PT pack off assembly 250/3500 psi. RIH with cap string. PU to 5000' @ 1600 lbs. Set hanger and static/dynamic pack offs. RDMO cap string truck. Hook up soap skid and start soap schedule. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 1 50-133-20657-00-00 216-132 Updated by DMA 06-21-23 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T-5AU 5,058 5,071 3,988’ 4,000’ 13’ 06/03/22 Open T-5AL 5,074 5,082 4,003’ 4,010’ 8’ 06/03/22 Open T-5B 5,103 5,121 4,030’ 4,047’ 18’ 06/03/22 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T-12U 5,783 5,799 4,691’ 4,707’ 16’ 06/03/22 Open T-12L 5,817 5,839 4,725’ 4,747’ 22’ 06/03/22 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 TOC @ ~950’ (2/4/17 CBL) 2 SL tag at 6342’ w 2” DDB (5-19-22) T5 T12 3//8” Capillary String Installed 08/04/23 Top Bottom MD 0’ 5,000’ 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: Install Cap String 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,866'7,801' 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 jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0384372 / FEE-CIRI 216-132 50-133-20657-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,360' Size 120' 1,509' MD See Attached Schematic 2,980psi 6,890psi 120'120' 1,509' July 4, 2023 N/A 8,846' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 1CO 701C Same 7,753'4-1/2" 1535 psi 8,846' 8,540' Length Baker Swell Packer & N/A 1,300 (MD) / 1,212 (TVD) & N/A 7,773' 7,801' 6,708' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic 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: 2023.06.20 14:58:10 - 08'00' Noel Nocas (4361) By Grace Christianson at 3:20 pm, Jun 20, 2023 323-354 DSR-6/21/23BJM 6/22/23 10-404 MDG 6/21/2023 2396 psi -bjm GCW 06/22/2023 06/23/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.23 09:09:28 -08'00' RBDMS JSB 062723 PBTD = 8,54 TVD = 7,447 TD = / TVD = 1 16 7-5/ 4-T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 2 SL tag at 6342 - 19-22) T5 T12 Updated by DMA 06-20-23 PROPOSED Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ JEWELRY DETAIL No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T-5AU 5,058 5,071 3,988’ 4,000’ 13’ 06/03/22 Open T-5AL 5,074 5,082 4,003’ 4,010’ 8’ 06/03/22 Open T-5B 5,103 5,121 4,030’ 4,047’ 18’ 06/03/22 Open T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T-12U 5,783 5,799 4,691’ 4,707’ 16’ 06/03/22 Open T-12L 5,817 5,839 4,725’ 4,747’ 22’ 06/03/22 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 TOC @ ~950’ (2/4/17 CBL) 2 SL tag at 6342’ w 2” DDB (5- 19-22) T5 T12 3/8” Capillary String Proposed to Install Top Bottom MD 0’ ±6,000’ Kaitlyn Barcelona Hilcorp Alaska, 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 or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, 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 or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 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D/ZhͲ>ŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϬϬϬƉƐŝ͘ ϯ͘ Z/,ĂŶĚƐĞƚƉůƵŐĂďŽǀĞƚŚĞƉĞƌĨŽƌĂƚŝŽŶƐKZƉĂƚĐŚĂĐƌŽƐƐƚŚĞƉĞƌĨŽƌĂƚŝŽŶƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ hƉĚĂƚĞĚďǇDϱͲϭϳͲϮϭ ^,Dd/ EŝŶŝůĐŚŝŬhŶŝƚ <ĂůŽƚƐĂηϭ Wd͗ϮϭϲͲϭϯϮ W/͗ϱϬͲϭϯϯͲϮϬϲϱϳͲϬϬͲϬϬ 3%7' ¶79' ¶ 7' ¶79' ¶ 5.% ¶^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶƚŽ ^ĞƚĞƉƚŚ ϴϰη yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟ ^ƵƌĨ ϭϮϬΖ ϳͲϱͬϴΗ ^ƵƌĨƐŐ Ϯϵ͘ϳη >ͲϴϬ d ϲ͘ϴϳϱ͟ ^ƵƌĨ ϭ͕ϱϬϵ͛ ϰͲϭͬϮΗ WƌŽĚƐŐ ϭϮ͘ϲη >ͲϴϬ tͬ,d ϯ͘ϵϱϴ͟ ^ƵƌĨ ϴ͕ϴϰϲ͛ EŽ͘ ĞƉƚŚ / /ƚĞŵ ϭ ϭ͕ϯϬϬ͛ ϯ͘ϵϱϴ͟ ĂŬĞƌ^ǁĞůůWĂĐŬĞƌ Ϯ ϱ͕ϭϰϰ͛ʹϱϭϳϵ͛Ϯ͘ϰϱ͟ĂŬĞƌ&ůŽ'ƵĂƌĚZĞƚƌŝĞǀĂďůĞWĂƚĐŚ ϯ ϴ͕ϱϰϬ͛ Eͬ /Wϭϭͬϭϳͬϭϳ WZ&KZdKEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &ƚ WĞƌĨ ĂƚĞ ^ƚĂƚƵƐ dϲ ϱ͕ϭϱϬ͛ ϱ͕ϭϳϱ͛ ϰ͕Ϭϳϰ͛ ϰ͕Ϭϵϴ͛ Ϯϱ ϯͬϰͬϭϳ WĂƚĐŚĞĚϯͬϮϳͬϮϭ dϳ ϱ͕ϯϯϯ͛ ϱ͕ϯϱϯ͛ ϰ͕ϮϱϬ͛ ϰ͕Ϯϲϵ͛ ϮϬ ϰͬϮϯͬϮϭ KƉĞŶ ϱ͕ϯϯϯ͛ ϱ͕ϯϱϯ͛ ϰ͕ϮϱϬ͛ ϰ͕Ϯϲϵ͛ ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϴ ϱ͕ϯϳϬ͛ ϱ͕ϯϴϳ͛ ϰ͕Ϯϴϲ͛ ϰ͕ϯϬϮ͛ ϭϳ ϰͬϮϯͬϮϭ KƉĞŶ ϱ͕ϯϳϮ͛ ϱ͕ϯϵϮ͛ ϰ͕Ϯϴϴ͛ ϰ͕ϯϬϳ͛ ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϭϰ ϲ͕Ϭϲϳ͛ ϲ͕ϬϴϮ͛ ϰ͕ϵϳϱ͛ ϰ͕ϵϵϬ͛ ϭϱ ϯͬϮͬϭϳ KƉĞŶ dϭϳ ϲ͕ϯϬϲ͛ ϲ͕ϯϮϲ͛ ϱ͕Ϯϭϯ͛ ϱ͕Ϯϯϯ͛ ϮϬ ϯͬϮͬϭϳ KƉĞŶ ϲ͕ϯϬϲ͛ ϲ͕ϯϮϲ͛ ϱ͕Ϯϭϯ͛ ϱ͕Ϯϯϯ͛ ϮϬ ϰͬϮϯͬϮϭ KƉĞŶ dϰϯ ϲ͕ϴϲϭ͛ ϲ͕ϴϳϬ͛ ϱ͕ϳϲϴ͛ ϱ͕ϳϳϳ͛ ϵ ϯͬϯͬϭϳ KƉĞŶ dϴϭ ϳ͕ϴϮϰ͛ ϳ͕ϴϯϯ͛ ϲ͕ϳϯϭ͛ ϲ͕ϳϰϬ͛ ϵ ϯͬϮͬϭϳ KƉĞŶ dϴϯ ϳ͕ϴϲϯ͛ ϳ͕ϴϳϵ͛ ϲ͕ϳϳϬ͛ ϲ͕ϳϴϲ͛ ϭϲ ϯͬϭͬϭϳ KƉĞŶ ϳ͕ϴϴϴ͛ ϳ͕ϴϵϲ͛ ϲ͕ϳϵϱ͛ ϲ͕ϴϬϯ͛ ϴ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϭϯ͛ ϴ͕Ϭϯϯ͛ ϲ͕ϵϮϬ͛ ϲ͕ϵϰϬ͛ ϮϬ ϯͬϭͬϭϳ KƉĞŶ ϴ͕Ϭϰϱ͛ ϴ͕Ϭϲϱ͛ ϲ͕ϵϱϮ͛ ϲ͕ϵϳϮ͛ ϮϬ ϯͬϭͬϭϳ KƉĞŶ ϴ͕Ϭϳϴ͛ ϴ͕ϭϭϬ ϲ͕ϵϴϱ͛ ϳ͕Ϭϭϳ͛ ϯϮ ϮͬϮϴͬϭϳ KƉĞŶ ϴ͕ϭϰϴ͛ ϴ͕ϭϲϴ͛ ϳ͕Ϭϰϳ͛ ϳ͕Ϭϳϱ͛ Ϯϴ ϮͬϮϴͬϭϳ KƉĞŶ dϭϰϬ ϴ͕ϱϲϲ͛ ϴ͕ϱϵϲ͛ ϳ͕ϰϳϯ͛ ϳ͕ϱϬϯ͛ ϯϬ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ ϴ͕ϲϭϴ͛ ϴ͕ϲϯϭ͛ ϳ͕ϱϮϱ͛ ϳ͕ϱϯϴ͛ ϭϯ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ DEdd/>^ ϳͲϱͬϴ͟ĞŵĞŶƚ:Žď͗ϵͲϳͬϴ͟ŚŽůĞ͘ϵϬďďůƐϭϮ͘ϬηůĂƐƐůĞĂĚ͕ĂŶĚϮϳďďůƐϭϱ͘ϰηůĂƐƐƚĂŝů͘ EŽůŽƐƐĞƐ͕ϮϬďďůƐĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ ϰͲϭͬϮ͟ĞŵĞŶƚ:Žď͗ ϲͲϯͬϰ͟ŚŽůĞ͘ϮϮϲďďůƐϭϯ͘ϱηůĂƐƐ'ůĞĂĚ͕ĂŶĚϯϵďďůƐϭϱ͘ϯηůĂƐƐ'ƚ Ăŝů͘ ϮϮďďůůŽƐƐĞƐĚƵƌŝŶŐũŽď͕ĂŶĚϭϮďďůƐĐŽŶƚĂŵŝŶĂƚĞĚĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ŝĚŶŽƚďƵŵƉƉůƵŐ͘ Ϯͬϰͬϭϳ^DdĨŽƵŶĚdŽĂƚΕϵϱϬ͛D͘ ´ ´ ´7 7 7 7 7 7 7 7 7 7 dKΛΕϵϱϬ͛ ;Ϯͬϰͬϭϳ>Ϳ &7FOHDQHGRXWWRKDUGILOODW ¶&70' hƉĚĂƚĞĚďǇ:>>ϱͬϮͬϮϮ WZKWK^ EŝŶŝůĐŚŝŬhŶŝƚ <ĂůŽƚƐĂηϭ Wd͗ϮϭϲͲϭϯϮ W/͗ϱϬͲϭϯϯͲϮϬϲϱϳͲϬϬͲϬϬ 3%7' ¶79' ¶ 7' ¶79' ¶ 5.% ¶^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶƚŽ ^ĞƚĞƉƚŚ ϴϰη yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟ ^ƵƌĨ ϭϮϬΖ ϳͲϱͬϴΗ ^ƵƌĨƐŐ Ϯϵ͘ϳη >ͲϴϬ d ϲ͘ϴϳϱ͟ ^ƵƌĨ ϭ͕ϱϬϵ͛ ϰͲϭͬϮΗ WƌŽĚƐŐ ϭϮ͘ϲη >ͲϴϬ tͬ,d ϯ͘ϵϱϴ͟ ^ƵƌĨ ϴ͕ϴϰϲ͛ EŽ͘ ĞƉƚŚ / /ƚĞŵ ϭ ϭ͕ϯϬϬ͛ ϯ͘ϵϱϴ͟ ĂŬĞƌ^ǁĞůůWĂĐŬĞƌ Ϯ ϱ͕ϭϰϰ͛ʹϱϭϳϵ͛Ϯ͘ϰϱ͟ĂŬĞƌ&ůŽ'ƵĂƌĚZĞƚƌŝĞǀĂďůĞWĂƚĐŚ ϯ ϴ͕ϱϰϬ͛ Eͬ /Wϭϭͬϭϳͬϭϳ WZ&KZdKEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &ƚ WĞƌĨ ĂƚĞ ^ƚĂƚƵƐ dϮʹ dϭϮ цϰ͕ϴϳϮ͛ цϱ͕ϴϯϵ͛ цϯ͕ϴϭϲ͛ цϰ͕ϳϰϳ͛ цϵϲϳ &hdhZ WZKWK^ dϲ ϱ͕ϭϱϬ͛ ϱ͕ϭϳϱ͛ ϰ͕Ϭϳϰ͛ ϰ͕Ϭϵϴ͛ Ϯϱ ϯͬϰͬϭϳ WĂƚĐŚĞĚϯͬϮϳͬϮϭ dϳ ϱ͕ϯϯϯ͛ ϱ͕ϯϱϯ͛ ϰ͕ϮϱϬ͛ ϰ͕Ϯϲϵ͛ ϮϬ ϰͬϮϯͬϮϭ KƉĞŶ ϱ͕ϯϯϯ͛ ϱ͕ϯϱϯ͛ ϰ͕ϮϱϬ͛ ϰ͕Ϯϲϵ͛ ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϴ ϱ͕ϯϳϬ͛ ϱ͕ϯϴϳ͛ ϰ͕Ϯϴϲ͛ ϰ͕ϯϬϮ͛ ϭϳ ϰͬϮϯͬϮϭ KƉĞŶ ϱ͕ϯϳϮ͛ ϱ͕ϯϵϮ͛ ϰ͕Ϯϴϴ͛ ϰ͕ϯϬϳ͛ ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϭϰ ϲ͕Ϭϲϳ͛ ϲ͕ϬϴϮ͛ ϰ͕ϵϳϱ͛ ϰ͕ϵϵϬ͛ ϭϱ ϯͬϮͬϭϳ KƉĞŶ dϭϳ ϲ͕ϯϬϲ͛ ϲ͕ϯϮϲ͛ ϱ͕Ϯϭϯ͛ ϱ͕Ϯϯϯ͛ ϮϬ ϯͬϮͬϭϳ KƉĞŶ ϲ͕ϯϬϲ͛ ϲ͕ϯϮϲ͛ ϱ͕Ϯϭϯ͛ ϱ͕Ϯϯϯ͛ ϮϬ ϰͬϮϯͬϮϭ KƉĞŶ dϰϯ ϲ͕ϴϲϭ͛ ϲ͕ϴϳϬ͛ ϱ͕ϳϲϴ͛ ϱ͕ϳϳϳ͛ ϵ ϯͬϯͬϭϳ KƉĞŶ dϴϭ ϳ͕ϴϮϰ͛ ϳ͕ϴϯϯ͛ ϲ͕ϳϯϭ͛ ϲ͕ϳϰϬ͛ ϵ ϯͬϮͬϭϳ KƉĞŶ dϴϯ ϳ͕ϴϲϯ͛ ϳ͕ϴϳϵ͛ ϲ͕ϳϳϬ͛ ϲ͕ϳϴϲ͛ ϭϲ ϯͬϭͬϭϳ KƉĞŶ ϳ͕ϴϴϴ͛ ϳ͕ϴϵϲ͛ ϲ͕ϳϵϱ͛ ϲ͕ϴϬϯ͛ ϴ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϭϯ͛ ϴ͕Ϭϯϯ͛ ϲ͕ϵϮϬ͛ ϲ͕ϵϰϬ͛ ϮϬ ϯͬϭͬϭϳ KƉĞŶ ϴ͕Ϭϰϱ͛ ϴ͕Ϭϲϱ͛ ϲ͕ϵϱϮ͛ ϲ͕ϵϳϮ͛ ϮϬ ϯͬϭͬϭϳ KƉĞŶ ϴ͕Ϭϳϴ͛ ϴ͕ϭϭϬ ϲ͕ϵϴϱ͛ ϳ͕Ϭϭϳ͛ ϯϮ ϮͬϮϴͬϭϳ KƉĞŶ ϴ͕ϭϰϴ͛ ϴ͕ϭϲϴ͛ ϳ͕Ϭϰϳ͛ ϳ͕Ϭϳϱ͛ Ϯϴ ϮͬϮϴͬϭϳ KƉĞŶ dϭϰϬ ϴ͕ϱϲϲ͛ ϴ͕ϱϵϲ͛ ϳ͕ϰϳϯ͛ ϳ͕ϱϬϯ͛ ϯϬ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ ϴ͕ϲϭϴ͛ ϴ͕ϲϯϭ͛ ϳ͕ϱϮϱ͛ ϳ͕ϱϯϴ͛ ϭϯ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ DEdd/>^ ϳͲϱͬϴ͟ĞŵĞŶƚ:Žď͗ϵͲϳͬϴ͟ŚŽůĞ͘ϵϬďďůƐϭϮ͘ϬηůĂƐƐůĞĂĚ͕ĂŶĚϮϳďďůƐϭϱ͘ϰηůĂƐƐƚĂŝů͘ EŽůŽƐƐĞƐ͕ϮϬďďůƐĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ ϰͲϭͬϮ͟ĞŵĞŶƚ:Žď͗ ϲͲϯͬϰ͟ŚŽůĞ͘ϮϮϲďďůƐϭϯ͘ϱηůĂƐƐ'ůĞĂĚ͕ĂŶĚϯϵďďůƐϭϱ͘ϯηůĂƐƐ'ƚ Ăŝů͘ ϮϮďďůůŽƐƐĞƐĚƵƌŝŶŐũŽď͕ĂŶĚϭϮďďůƐĐŽŶƚĂŵŝŶĂƚĞĚĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ŝĚŶŽƚďƵŵƉƉůƵŐ͘ Ϯͬϰͬϭϳ^DdĨŽƵŶĚdŽĂƚΕϵϱϬ͛D͘ ´ ´ ´7 7 7 7 7 7 7 7 7 7 dKΛΕϵϱϬ͛ ;Ϯͬϰͬϭϳ>Ϳ &7FOHDQHGRXWWRKDUGILOODW ¶&70' 7± 7 David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2021 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 KALOTSA 1 50133206570000 216132 3/27/2021 SET PATCH/GAMMA RAY Yellowjacket KALOTSA 1 50133206570000 216132 4/23/2021 PERF GAMMA RAY / GPT Yellowjacket KALOTSA 2 50133206590000 216155 4/10/2021 PERF GAMMA RAY Yellowjacket PAXTON 2 50133205730000 207164 2/23/2021 PERF GAMMA RAY Yellowjacket PAXTON 9 50133206470000 214173 3/19/2021 PERF GAMMA RAY Yellowjacket PAXTON 9 50133206470000 214173 4/10/2021 PERF GAMMA RAY Yellowjacket PAXTON 9 50133206470000 216132 4/23/2021 PERF GAMMA RAY Yellowjacket PAXTON 10 50133206910000 220064 4/13/2021 SET WRP / CCL Yellowjacket PAXTON 10 50133206910000 220064 4/20/2021 SET WRP / CCL Yellowjacket SD-1A 50133100020100 185208 4/27/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. PTD: 2161320 E-Set: 35202 06/02/2021 David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2021 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 KALOTSA 1 50133206570000 216132 3/27/2021 SET PATCH/GAMMA RAY Yellowjacket KALOTSA 1 50133206570000 216132 4/23/2021 PERF GAMMA RAY / GPT Yellowjacket KALOTSA 2 50133206590000 216155 4/10/2021 PERF GAMMA RAY Yellowjacket PAXTON 2 50133205730000 207164 2/23/2021 PERF GAMMA RAY Yellowjacket PAXTON 9 50133206470000 214173 3/19/2021 PERF GAMMA RAY Yellowjacket PAXTON 9 50133206470000 214173 4/10/2021 PERF GAMMA RAY Yellowjacket PAXTON 9 50133206470000 216132 4/23/2021 PERF GAMMA RAY Yellowjacket PAXTON 10 50133206910000 220064 4/13/2021 SET WRP / CCL Yellowjacket PAXTON 10 50133206910000 220064 4/20/2021 SET WRP / CCL Yellowjacket SD-1A 50133100020100 185208 4/27/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. PTD: 2161320 E-Set: 35203 06/02/2021 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: N2 / 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 8,866 feet 8,540 feet true vertical 7,773 feet N/A feet Effective Depth measured 8,540 feet 1,300 feet true vertical 7,447 feet 1,212 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 Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr; N/A 1,300' MD 1,212' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 2,980psi 8,430psi 120' 1,360'6,890psi Collapse 1,410psi 4,790psi 7,500psi Casing Structural 16" 7-5/8" Length 120' 1,509' 8,846' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 52 Casing Pressure Liner 1,203 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-111 & 321-187 118 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 49 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-132 50-133-20657-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 800 Kalotsa 1 N/A C061505 (SHL), ADL384372 (TPH, BHL) Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ninilchik Field - Beluga/Tyonek Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 4-1/2"8,846'7,753' WINJ WAG 346 Water-Bbl MD 120' 1,509' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:01 pm, May 18, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.14 15:39:40 -08'00' Taylor Wellman (2143) RBDMS HEW 5/20/2021 BJM 9/27/21 DSR-5/18/21 SFD 5/21/2021 Rig Start Date End Date 3/25/21 4/23/21 03/24/2021 - Wednesday PTW, JSA with crews. MIRU SLB CTU 13 with 1.75" CT. 24 hr BOPE test witness notification sent via online submission on 3/23/2021 @ 1545 hrs. Witness waived by Jim Regg on 3/23/21 @ 1554 hrs. Start BOPE test. Test all rams and valves 250/4,000 psi. Load 400 bbls in upright. Mix up 6% KCL and heat fluid to 90°F with hot oil truck. 03/25/2021 - Thursday SLB Coiled tubing arrive on location. Conduct JSA and approve PTW. MIRU. MU Cleanout BHA. 1.90" CTC, 1.75" DFCV, 1.5" straight bar, 1.5" JSN. PT out to choke skid, 250 psi low / 3,500 psi high. Open well and RIH. Close wing valve. RIH and dry tag at 6,470'. Cool down N2 pump and mix gel in batchmixer. Base fluid is 6% KCl. Start pumping gel (flow vis) /F104 at 0.3 bpm and 500 scf/m N2 and take bites of fill. Take 100' bites, then short trips to string out sand. Increase pump rate to 0.4 bpm and N2 to 700 scf/m, get better foam quality at tanks. Clean out to 7,200', De-foamer is not keeping up with foam at return tank. Cut back rate on fluid and N2, start to POOH. At surface with coil. Displace coil to return tank. Laydown lubricator and set injector on the back deck for the night. Install night cap on well. Plan to resume next day. 03/26/2021- Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 1 50-133-20657-00-00 216-132 SLB coil arrive on location. Conduct JSA and approve PTW. MU lubricator and stab MU to BOP's. PT out to choke skid to 250 psi low / 3,500 psi high. RIH with coil and dry tag at 6,580' ctmd. PU weight = 18K Pump 0.3 bpm of gel/surfactant and 500 scf/m N2. Take 100' bites of fill fillowed by short trips to string out sand. Getting returns of foam and fine sand at surface. Clean out to 7,100' and chase sand up hole. Getting a large amount of sand and foam at surface. Continue to POOH to 2,000'. Swap to nitrified/water. RIH jetting to 4,100' and POOH chasing sand to surface. Chase sand to surface, blowdown coil with N2. Laydown coil lubricator and injector. Plan to set patch with E-line the next day. Clean out to 7,100' Clean out to 7,200', Rig Start Date End Date 3/25/21 4/23/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 1 50-133-20657-00-00 216-132 03/27/2021 - Saturday 04/23/2021- Friday PTW and JSA. Rig up equipment. PT lubricator to 250 psi low and 3,000 psi high. RIH w/GPT too and tie into OHL. Ran GPT log from Surface to tag depth 6,347' (tag high) which 7,801' was coil tubing measurements tag. Tried a few times to get past but had GPT on bottom and didn't want to get rough with it. It was clean pickup. POOH. Send log to town. Log on depth. RIH w/ 2" x 20' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Town said to add 1'/ perf from 6,306' to 6,326'. Spot and fire gun w/FTP - 115 psi/Rate -850K. after 1 min- FTP - 115 psi/Rate - 900K, 10 min - FTP -115 psi/Rate - 900K. and 15 min - FTP - 115 psi/Rate - 900K. POOH. All shots fired/Gun wet. RIH w/ 2" x 17' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 5,370' to 5,387'. Spot and fire gun w/FTP -120.7 psi/Rate 937K, 5 min - FTP - 134 psi/Rate - 934.1K, 10 min -FTP - 118.2 psi/rate - 962K and 15 min - FTP - 119.1 psi/942K Rate. All shot/gun wet. RIH w/ 2" x 20' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 5,333' to 5,353'. Spot and fire gun w/FTP - 117 psi/Rate 973K. After 3 min - FTP - 117.1 psi/Rate - 1.03 million. 5 min - FTP - 117.5 psi/1.01 million, 10 min - FTP - 117.6 psi/Rate 1.04 million and 15 min - FTP - 117.5 psi/1.04 million and climbing. all shots fired/Gun was wet. Rig down equipment, secure well. Do a walk around and turn well over to field. Yellow Jacket E-line arrive on location. Conduct JSA and approve PTW. MU lubricator and 3.75" gauge ring/junk basket. PT lubricator. RIH to 5,300' with 3.75" gauge ring/junk basket. While pulling out of hole, having weight fluctuations with gauge ring. At surface, find minimal sand in junk basket and around tool string. MU Baker 4.5" FloGard straddle patch assembly. Distance between element to element = 34.5'. OD of elements are 3.70". RIH with patch and tie-in above patch setting depth to minimize running across perf interval. Send correlation data to Geo. Confirm log is on depth. Move patch set depth uphole 1' to move away from collar @ 5,146'. Set patch from 5,144'- 5,178.5' (Covering perfs 5,150' - 5,175'). RDMO. 03/28/2021 - Sunday SLB coiled tubing arrive. Conduct JSA and approve PTW. MU lubricator and cleanout BHA. MU on top of BOP's and PT out to choke. RIH and dry tag at 7020' ctmd. Start Nitrified foam fill cleanout. Pump 0.35 bpm fluid/500 scf/m of N2. Take 150' bites, followed short trips to string out sand in wellbore. Starting to see signs of hard fill at 7,790', Chase returns uphole to 6,000'. RIH to 7,790', start jetting on hard fill. Try different speeds and jetting on fill. Clean to 7,801' and can't get any deeper. PUH chasing solids to 1400' ctmd. Getting foam/solids at return tanks. RIH and swap to Nitrogen only. RIH to 7,800' and circulate N2 around nozzle. WHP = 420 psi. POOH pumping nitrogen, taking returns to surface. Once getting only N2 back, close in choke, down on N2 pump. WHP = 750 psi. Coil at surface. Nipple down BOPs from tree. Hand well over to operations. Leave equipment on location. De-mob next day. o perf from 5,333' to 5,353'.Spot and fire gun w . Clean to 7,801' and can't get any deeper. o perf from 5,370' to 5,387'. Spot and fire gun w / perf from 6,306' to 6,326'. Spot and fire gun w Set patch from 5,144'- 5,178.5' (Covering perfs 5,150' - 5,175'). Updated by DMA 4-29-21 SCHEMATIC Ninilchik Unit Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84# X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7# L-80 BTC 6.875” Surf 1,509’ 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958” Surf 8,846’ No. Depth ID Item 1 1,300’ 3.958” Baker Swell Packer 2 5,144’ – 5179’ 2.45” Baker FloGuard Retrievable Patch 3 8,540’ N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Perf Date Status T6 5,150’ 5,175’ 4,074’ 4,098’ 25 3/4/17 Patched 3/27/21 T7 5,333’ 5,353’ 4,250’ 4,269’ 20 4/23/21 Open 5,333’ 5,353’ 4,250’ 4,269’ 20 3/4/17 Open T8 5,370’ 5,387’ 4,286’ 4,302’ 17 4/23/21 Open 5,372’ 5,392’ 4,288’ 4,307’ 20 3/4/17 Open T14 6,067’ 6,082’ 4,975’ 4,990’ 15 3/2/17 Open T17 6,306’ 6,326’ 5,213’ 5,233’ 20 3/2/17 Open 6,306’ 6,326’ 5,213’ 5,233’ 20 4/23/21 Open T43 6,861’ 6,870’ 5,768’ 5,777’ 9 3/3/17 Open T81 7,824’ 7,833’ 6,731’ 6,740’ 9 3/2/17 Open T83 7,863’ 7,879’ 6,770’ 6,786’ 16 3/1/17 Open 7,888’ 7,896’ 6,795’ 6,803’ 8 3/1/17 Open T90 8,013’ 8,033’ 6,920’ 6,940’ 20 3/1/17 Open 8,045’ 8,065’ 6,952’ 6,972’ 20 3/1/17 Open 8,078’ 8,110 6,985’ 7,017’ 32 2/28/17 Open 8,148’ 8,168’ 7,047’ 7,075’ 28 2/28/17 Open T140 8,566’ 8,596’ 7,473’ 7,503’ 30 2/28/17 Isolated 8,618’ 8,631’ 7,525’ 7,538’ 13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. Did not bump plug. 2/4/17 SCMT found ToC at ~950’ MD. 1 16” 7-5/8” 4-1/2” T140 T8 T90 T83 T81 T43 T17 T14 T7 T6 3 TOC @ ~950’ (2/4/17 CBL) 2 CT cleaned out to hard fill at 7801’ CTMD (3/28/21) 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: _________ 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.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,866'fill: 7801' MD 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 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: April 26, 2021 N/A 8,846' Perforation Depth MD (ft): See Attached Schematic 8,846'7,753'4-1/2" 16" 7-5/8" 120' 1,509' 2,980psi 6,890psi 120' 1,360' 120' 1,509' N/A TVD Burst N/A 8,430psi MDLengthSize CO 701C 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), ADL384372 (TPH, BHL) 216-132 50-133-20657-00-00 Kalotsa 1 Ninilchik Field - Beluga/Tyonek Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic ryan.rupert@hilcorp.com 7,773'8,540'7,447'~2372 8,540' Baker Swell Pkr; N/A 1,300' MD/ 1,212' TVD; N/A; N/A Perforation Depth TVD (ft):Tubing Size: m n P t _ 66 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:11 am, Apr 12, 2021 321-187 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.09 16:21:39 -08'00' Taylor Wellman (2143) 10-404 DSR-4/12/21BJM 4/15/21 DLB 04/12/2021 X Comm 4/19/21 dts 4/19/2021 RBDMS HEW 4/19/2021 Well Prognosis Well: Kalotsa-01 Date: 4/9/2021 Well Name:Kalotsa-01 API Number:50-113-20657-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:216-132 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Todd Sidoti (907) 632-4113 (C) Maximum Expected BHP:~ 3045 psi @ 6,731’ TVD (0.452psi/ft. assumed to deepest unknown sand- T-81) Max. Potential Surface Pressure:~ 2372 psi Using Max BHP minus 0.1 psi/ft. gas gradient to surface). Well Summary Kalotsa 1 had lost almost 1.5 MMCFD since 1/22/2021. A SL drift & tag with a 2-1/2” slickline bailer was carried out on 1/28/2021 and found fill at approximately 5510’ MD –just below the T9A perforations. As of 3/20/21 the well had stopped producing and meaningful rate. CT performed a FCO in late March-2021 and a patch was set across the T-6 to hopefully isolate the sand production. The FCO re-accessed 2000’+ of the wellbore, but tagged hard at ~7800’ MD. The operation concluded there, and the well brought online. It has since slowly built strength and seems to have leveled out at ~650mcf. Hilcorp intends to conduct surveillance on this well to diagnose the current wellbore and flow conditions. If necessary, proposed perfs / reperfs are listed below. These will be shot in an attempt to restore the well to prior rates. Notes Regarding Wellbore Condition x Min ID: 2.45” at Baker patch from 5144’ – 5179’ MD x Max inclination = 47deg sail angle from 1400 – 3800’ MD x 3/28/21 drift CT cleaned out to 7801’ CTMD and tagged hard Well Prognosis Well: Kalotsa-01 Date: 4/9/2021 EL Perforating 1. MIRU EL 2. PT BOP equipment to 250 psi Low / 3,000 psi High. 3. Rig up perf guns (Likely 2” 4-6 spf) 4. RIH and perforate the sands listed in the table below as needed Sand Perforation Top Perforation Bottom Perforation Top Perforation Bottom Total Footage (MD)(MD)(MD)(MD)(MD) T-7 ±5,333'±5,353'±4,250'±4,269'20' T-8 ±5,370'±5,387'±4,286'±4,302'17' T-17 ±6,306'±6,328'±5,214'±5,236'22' T-43 ±6,861'±6,870'±5,768'±5,777'9' Consult with OE for what WHP to use. Some interval(s) may be shot flowing as well 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. Anthony McConkey: RE - 529-6199 ii. Matthew Petrowsky: Geo – 814-421-6753 5. RD E-Line Unit and turn well over to production. Attachments 1. Current schematic Updated by CRR 4-9-21 SCHEMATIC Ninilchik Well Kalotsa #1 PTD:216-132 API: 50-133-20657-00-00 PBTD = 8,540’ / TVD = 7,447’ TD = 8,866’ / TVD = 7,773’ RKB = 18’CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84# X-56 Weld 15.01”Surf 120' 7-5/8"Surf Csg 29.7#L-80 BTC 6.875”Surf 1,509’ 4-1/2"Prod Csg 12.6#L-80 DWC/C HT 3.958”Surf 8,846’ No.Depth ID Item 1 1,300’3.958”Baker Swell Packer 2 5,144’ – 5179’2.45”Baker FloGuard Retrievable Patch 3 8,540’N/A CIBP 11/17/17 PERFORATON DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Ft Perf Date Status T6 5,150’5,175’4,074’4,098’25 3/4/17 Patched 3/27/21 T7 5,333’5,353’4,250’4,269’20 3/4/17 Open T8 5,372’5,392’4,288’4,307’20 3/4/17 Open T14 6,067’6,082’4,975’4,990’15 3/2/17 Open T17 6,306’6,326’5,213’5,233’20 3/2/17 Open T43 6,861’6,870’5,768’5,777’9 3/3/17 Open T81 7,824’7,833’6,731’6,740’9 3/2/17 Open T83 7,863’7,879’6,770’6,786’16 3/1/17 Open T83 7,888’7,896’6,795’6,803’8 3/1/17 Open T90 8,013’8,033’6,920’6,940’20 3/1/17 Open T90 8,045’8,065’6,952’6,972’20 3/1/17 Open T90 8,078’8,110 6,985’7,017’32 2/28/17 Open T90 8,148’8,168’7,047’7,075’28 2/28/17 Open T140 8,566’8,596’7,473’7,503’30 2/28/17 Isolated T140 8,618’8,631’7,525’7,538’13 2/28/17 Isolated CEMENT DETAILS 7-5/8” Cement Job: 9-7/8” hole. 90bbls 12.0# Class A lead, and 27bbls 15.4# Class A tail. No losses, 20bbls cement to surface. 4-1/2” Cement Job: 6-3/4” hole. 226bbls 13.5# Class G lead, and 39bbls 15.3# Class G tail. 22bbl losses during job, and 12bbls contaminated cement to surface. 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:ƵůǇϮϬϭϳͿ ΎΎdͲϭϰĂŶĚdͲϰϯĂƌĞ ůŝŬĞůǇƚŽŽƚŝŐŚƚƚŽĞĨĨĞĐƚ&KǁŚĞŶƵŶĐŽǀĞƌĞĚ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗<ĂůŽƚƐĂͲϬϭ ĂƚĞ͗ϯͬϱͬϮϬϮϬ ŽŝůĞĚdƵďŝŶŐ ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐ͕WdKWƚŽϰ͕ϬϬϬƉƐŝ,ŝϮϱϬ>Žǁ͘ ĂͿ EŽƚŝĨǇK'ϮϰŚƌƐ͘ŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ďͿ /ĨWĞƚƌŽƐƉĞĐd͕ǁŝůůŶĞĞĚKWƚĞƐƚǁŚĞŶƌŝŐƵƉŽŶǁĞůů ĐͿ /Ĩ^>d͕ǁŝůůďĞĐŽǀĞƌĞĚďǇ ǁĞĞŬůǇKWƚĞƐƚ͕ŝĨƐƚŝůůǀĂůŝĚ͘ Ϯ͘ ZhEϮƉƵŵƉŝŶŐƵŶŝƚƚŽŽŝůĨŽƌĂŶŝƚƌŝĨŝĞĚĐůĞĂŶŽƵƚ ϯ͘ DŝǆƐƵĨĨŝĐŝĞŶƚϲй<>ĨŽƌĐůĞĂŶŽƵƚũŽď ϰ͘ Z/,ǁŝƚŚĂƐůŝĐŬ,ĨŽƌĐůĞĂŶŽƵƚĂŶĚĞƐƚĂďůŝƐŚƚĂŐĚĞƉƚŚ͘ ϱ͘ WĞƌĨŽƌŵĨŝůůĐůĞĂŶŽƵƚ ƚĂŬŝŶŐƌĞƚƵƌŶƐ ƚŽƚĂŶŬƐĚŽǁŶƚŽ WdŽĨϴϱϰϬ͛D ĂͿ DŝŶŝŵƵŵĐůĞĂŶŽƵƚĚĞƉƚŚŝƐƚŽ ϲϰϬϬ͛DƚŽƉƌŽǀŝĚĞƐŽŵĞƌĂƚŚŽůĞ ďĞůŽǁƚŚĞdͲϭϳ ƐĂŶĚ ďͿ tŽƌŬŝŶŐĨůƵŝĚƐŚŽƵůĚ ďĞϲй<> ĐͿ tŝůů ŶĞĞĚŶŝƚƌŽŐĞŶͬĨŽĂŵ ĚͿ ts ĨƌŽŵdͲϲƉĞƌĨƐƚŽWd ŝƐΕϱϭ ďďůƐ ĞͿ tsĨƌŽŵdͲϲƉĞƌĨƐƚŽŵŝŶŝŵƵŵĐůĞĂŶŽƵƚĚĞƉƚŚŽĨϲϰϬϬ͛DŝƐΕϭϵďďůƐ ĨͿ ŽĐƵŵĞŶƚ ĂůůƉƵŵƉĞĚĂŶĚƌĞĐŽǀĞƌĞĚǀŽůƵŵĞƐ͘tĂŶƚƐŽůŝĚƐǀƐ͘ǁĂƚĞƌǀŽůƵŵĞĂƐǁĞůů ϲ͘ WKK,ĐŚĂƐŝŶŐĨŝůůƵƉŚŽůĞ ϳ͘ tŚĞŶǁĞůůŝƐĐůĞĂŶĞĚŽƵƚƚŽWd͕KZŵŝŶŝŵĂůĂĚĚŝƚŝŽŶĂůƉƌŽŐƌĞƐƐŝƐďĞŝŶŐŵĂĚĞ͕ ƐƚĂŶĚďĂĐŬ d ĂŶĚƌŝŐƵƉ>ƉĞƌďĞůŽǁĨŽƌƉĂƚĐŚƐĞƚ ϴ͘ KŶĐĞƉĂƚĐŚŝƐƐĞƚ͕Z/,ǁŝƚŚ ƐůŝĐŬĐůĞĂŶŽƵƚ,ĂŶĚĞƐƚĂďůŝƐŚƚĂŐĚĞƉƚŚ͘ ĂͿ hƐĞĐĂƌĞǁŚĞŶƌƵŶŶŝŶŐƚŚƌŽƵŐŚƉĂƚĐŚ ďͿ s͛ƐǁŝůůƐůŽǁĚŽǁŶĂďŽǀĞƚŚĞƉĂƚĐŚ͕ƐŽŵĂŬĞƐƵƌĞĂŶĚĐŚĂƐĞŽƵƚŽĨŚŽůĞ͕ĂŶĚͬŽƌƉƵŵƉ ƐǁĞĞƉƐĂƐŶĞĐĞƐƐĂƌǇ ϵ͘ WĞƌĨŽƌŵĨŝůůĐůĞĂŶŽƵƚ ƚĂŬŝŶŐƌĞƚƵƌŶƐ ƚŽƚĂŶŬƐĚŽǁŶƚŽ WdŽĨϴϱϰϬ͛D ϭϬ͘ KŶĐĞĨŝůůƌĞƚƵƌŶƐŚĂǀĞƐƚŽƉƉĞĚ͕ĂŶĚǁĞůůŝƐĐůĞĂŶĞĚŽƵƚƚŽWd͕ƐǁŝƚĐŚŽǀĞƌƚŽũƵƐƚŶŝƚƌŽŐĞŶ͕ĂŶĚ ĨůŽǁǁĞůůƚŽƚĂŶŬƐƵŶůŽĂĚŝŶŐĂŶǇǁĞůůďŽƌĞĨůƵŝĚƉƌĞƐĞŶƚ͘ ϭϭ͘ KŶĐĞŐĂƐŝƐďĂĐŬƚŽƐƵƌĨĂĐĞĂŶĚEϮƌĞƚƵƌŶƐŚĂǀĞƐƵďƐŝĚĞĚ͕ƌŽůůǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϭϮ͘ ZDKd EŽƚŝĨǇK'ϮϰŚƌƐ͘ŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ďͿ /ĨWĞƚƌŽƐƉĞĐd͕ǁŝůůŶĞĞĚKWƚĞƐƚǁŚĞŶƌŝŐƵƉŽŶǁĞůů ĐͿ /Ĩ^>d͕ǁŝůůďĞĐŽǀĞƌĞĚďǇ ǁĞĞŬůǇKWƚĞƐƚ͕ŝĨƐƚŝůůǀĂůŝĚ͘ WdKWƚŽϰ͕ϬϬϬƉƐŝ,ŝϮϱϬ>Žǁ͘ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗<ĂůŽƚƐĂͲϬϭ ĂƚĞ͗ϯͬϱͬϮϬϮϬ >WĂƚĐŚ ^Ğƚ ϭ͘ D/Zh > Ϯ͘ WdKWĞƋƵŝƉŵĞŶƚƚŽ ϮϱϬƉƐŝ>Žǁͬ ϯϬϬϬ ƉƐŝ,ŝŐŚ͘ ϯ͘ ŽŶĚƵĐƚĚƌŝĨƚƚŽϱϭϴϬ͛DũƵƐƚďĞůŽǁƉĂƚĐŚƐĞƚŝŶƚĞƌǀĂů͘ ϰ͘ Wh͕Z/,ǁŝƚŚ ƌĞƚƌŝĞǀĂďůĞ ƉĂƚĐŚĂŶĚ ƐĞƚ ĂĐƌŽƐƐ dͲϲŝŶƚĞƌǀĂů ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ Ĩƚ͘ dͲϲ ϱϭϱϬ ϱϭϳϱ ϰϬϳϰ ϰϬϵϴ Ϯϱ Ă͘hƐĞ'ĂŵŵĂͬ>ƚŽĐŽƌƌĞůĂƚĞ͘ ď͘ DĂŬĞĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĂŶĚƐĞŶĚůŽŐŝŶ ƚŽ͕ ZĞƐĞƌǀŽŝƌŶŐŝŶĞĞƌĂŶĚƚŚĞ'ĞŽůŽŐŝƐƚ͘ Ă͘ ŶƚŚŽŶǇDĐŽŶŬĞǇ͗Z Ͳ ϱϮϵͲϲϭϵϵ ď͘ DĂƚƚŚĞǁWĞƚƌŽǁƐŬǇ͗'ĞŽ ʹ ϴϭϰͲϰϮϭͲϲϳϱϯ ϱ͘ ĨƚĞƌƉĂƚĐŚŝƐƐĞƚ͕ĚƌŝĨƚ ĂŶĚƚĂŐ ƚŽWd ƚŚƌŽƵŐŚƉĂƚĐŚ ĂŶĚĞƐƚĂďůŝƐŚƚŽƉŽĨĨŝůůƚŽŝŶĨŽƌŵĂĚĚŝƚŝŽŶĂů dǁŽƌŬ ϲ͘ ZDK> KEd/E'E/^͗ Ͳ /ĨƉĂƚĐŚĞƐĐĂŶ͛ƚďĞƐĞƚŽŶ >ŵĂǇŵŽǀĞƚŽĞͲĐŽŝů Ͳ WůĂŶƚŽƐĞƚƉĂƚĐŚǁŝƚŚdƐƚŽŽĚďĂĐŬ͕ďƵƚŵĂǇĐŚĂŶŐĞŽƌĚĞƌŽĨŽƉĞƌĂƚŝŽŶƐĚĞƉĞŶĚŝŶŐŽŶǁĞůů ĐŽŶĚŝƚŝŽŶƐ ƚƚĂĐŚŵĞŶƚƐ ϭ͘ ƵƌƌĞŶƚƐĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ^ƚĂŶĚĂƌĚtĞůůƉƌŽĐĞĚƵƌĞ ʹ EϮKƉĞƌĂƚŝŽŶƐ Z/,ǁŝƚŚ ƌĞƚƌŝĞǀĂďůĞ ƉĂƚĐŚĂŶĚ ƐĞƚ ĂĐƌŽƐƐ dͲϲŝŶƚĞƌǀĂů hƉĚĂƚĞĚďǇ ZZϯͲϬϭͲϮϭ ^,Dd/ EŝŶŝůĐŚŝŬ tĞůů <ĂůŽƚƐĂηϭ Wd͗ϮϭϲͲϭϯϮ W/͗ϱϬͲϭϯϯͲϮϬϲϱϳͲϬϬͲϬϬ 3%7' ¶3%79' ¶ 7' ¶ 79' ¶ 5.% ¶^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘/dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌ ʹ ƌŝǀĞŶƚŽ ^ĞƚĞƉƚŚ ϴϰη yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟^ƵƌĨ ϭϮϬΖ ϳͲϱͬϴΗ ^ƵƌĨƐŐ Ϯϵ͘ϳη >ͲϴϬ dϲ͘ϴϳϱ͟^ƵƌĨ ϭ͕ϱϬϵ͛ ϰͲϭͬϮΗ WƌŽĚƐŐ ϭϮ͘ϲη >ͲϴϬ tͬ,d ϯ͘ϵϱϴ͟^ƵƌĨ ϴ͕ϴϰϲ͛ :t>Zzd/> EŽ͘ĞƉƚŚ /K/ƚĞŵ ϭ ϭ͕ϯϬϬ͛ϯ͘ϵϱϴ͟ϲ͘ϴϳϱ͟ĂŬĞƌ^ǁĞůůWĂĐŬĞƌ Ϯ ϴ͕ϱϰϬ͛Eͬϯ͘ϱϬ͟/W ϭϭͬϭϳͬϭϳ WZ&KZdKEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &ƚ ĂƚĞ ^ƚĂƚƵƐ dϲ ϱ͕ϭϱϬ͛ϱ͕ϭϳϱ͛ϰ͕Ϭϳϰ͛ϰ͕Ϭϵϴ͛Ϯϱ ϯͬϰͬϭϳ KƉĞŶ dϳ ϱ͕ϯϯϯ͛ϱ͕ϯϱϯ͛ϰ͕ϮϱϬ͛ϰ͕Ϯϲϵ͛ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϴ ϱ͕ϯϳϮ͛ϱ͕ϯϵϮ͛ϰ͕Ϯϴϴ͛ϰ͕ϯϬϳ͛ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϭϰ ϲ͕Ϭϲϳ͛ϲ͕ϬϴϮ͛ϰ͕ϵϳϱ͛ϰ͕ϵϵϬ͛ϭϱ ϯͬϮͬϭϳ KƉĞŶ dϭϳ ϲ͕ϯϬϲ͛ϲ͕ϯϮϲ͛ϱ͕Ϯϭϯ͛ϱ͕Ϯϯϯ͛ϮϬ ϯͬϮͬϭϳ KƉĞŶ dϰϯ ϲ͕ϴϲϭ͛ϲ͕ϴϳϬ͛ϱ͕ϳϲϴ͛ϱ͕ϳϳϳ͛ϵ ϯͬϯͬϭϳ KƉĞŶ dϴϭ ϳ͕ϴϮϰ͛ϳ͕ϴϯϯ͛ϲ͕ϳϯϭ͛ϲ͕ϳϰϬ͛ϵ ϯͬϮͬϭϳ KƉĞŶ dϴϯ ϳ͕ϴϲϯ͛ϳ͕ϴϳϵ͛ϲ͕ϳϳϬ͛ϲ͕ϳϴϲ͛ϭϲ ϯͬϭͬϭϳ KƉĞŶ dϴϯ ϳ͕ϴϴϴ͛ϳ͕ϴϵϲ͛ϲ͕ϳϵϱ͛ϲ͕ϴϬϯ͛ϴ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϭϯ͛ϴ͕Ϭϯϯ͛ϲ͕ϵϮϬ͛ϲ͕ϵϰϬ͛ϮϬ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϰϱ͛ϴ͕Ϭϲϱ͛ϲ͕ϵϱϮ͛ϲ͕ϵϳϮ͛ϮϬ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϳϴ͛ϴ͕ϭϭϬ ϲ͕ϵϴϱ͛ϳ͕Ϭϭϳ͛ϯϮ ϮͬϮϴͬϭϳ KƉĞŶ dϵϬ ϴ͕ϭϰϴ͛ϴ͕ϭϲϴ͛ϳ͕Ϭϰϳ͛ϳ͕Ϭϳϱ͛Ϯϴ ϮͬϮϴͬϭϳ KƉĞŶ dϭϰϬ ϴ͕ϱϲϲ͛ϴ͕ϱϵϲ͛ϳ͕ϰϳϯ͛ϳ͕ϱϬϯ͛ϯϬ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ dϭϰϬ ϴ͕ϲϭϴ͛ϴ͕ϲϯϭ͛ϳ͕ϱϮϱ͛ϳ͕ϱϯϴ͛ϭϯ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ DEd d/>^ ϳͲϱͬϴ͟ĞŵĞŶƚ:Žď͗ϵͲϳͬϴ͟ŚŽůĞ͘ϵϬďďůƐϭϮ͘ϬηůĂƐƐůĞĂĚ͕ĂŶĚϮϳďďůƐϭϱ͘ϰηůĂƐƐƚĂŝů͘ EŽůŽƐƐĞƐ͕ϮϬďďůƐĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ ϰͲϭͬϮ͟ĞŵĞŶƚ:Žď͗ ϲͲϯͬϰ͟ŚŽůĞ͘ϮϮϲďďůƐϭϯ͘ϱηůĂƐƐ'ůĞĂĚ͕ĂŶĚϯϵďďůƐϭϱ͘ϯηůĂƐƐ'ƚĂŝů͘ ϮϮďďůůŽƐƐĞƐĚƵƌŝŶŐũŽď͕ĂŶĚϭϮďďůƐĐŽŶƚĂŵŝŶĂƚĞĚĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ŝĚŶŽƚďƵŵƉƉůƵŐ͘ Ϯͬϰͬϭϳ^DdĨŽƵŶĚdŽĂƚΕϵϱϬ͛D͘ ´ ´ ´7 7 7 7 7 7 7 7 7 7 dKΛΕϵϱϬ͛ ;Ϯͬϰͬϭϳ>Ϳ &ŝůůƚĂŐŐĞĚĂƚϱϱϭϬ͛ ;ϭͬϮϴͬϮϭͿ hƉĚĂƚĞĚďǇ ZZϯͲϬϭͲϮϭ WZKWK^^,Dd/ EŝŶŝůĐŚŝŬ tĞůů <ĂůŽƚƐĂηϭ Wd͗ϮϭϲͲϭϯϮ W/͗ϱϬͲϭϯϯͲϮϬϲϱϳͲϬϬͲϬϬ 3%7' ¶3%79' ¶ 7' ¶ 79' ¶ 5.% ¶^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘/dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌ ʹ ƌŝǀĞŶƚŽ ^ĞƚĞƉƚŚ ϴϰη yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟^ƵƌĨ ϭϮϬΖ ϳͲϱͬϴΗ ^ƵƌĨƐŐ Ϯϵ͘ϳη >ͲϴϬ dϲ͘ϴϳϱ͟^ƵƌĨ ϭ͕ϱϬϵ͛ ϰͲϭͬϮΗ WƌŽĚƐŐ ϭϮ͘ϲη >ͲϴϬ tͬ,d ϯ͘ϵϱϴ͟^ƵƌĨ ϴ͕ϴϰϲ͛ :t>Zzd/> EŽ͘ĞƉƚŚ /K/ƚĞŵ ϭ ϭ͕ϯϬϬ͛ϯ͘ϵϱϴ͟ϲ͘ϴϳϱ͟ĂŬĞƌ^ǁĞůůWĂĐŬĞƌ Ϯ ϱ͕ϭϱϬ͛Ϯ͘ϰϰϭ͟ZĞƚƌŝĞǀĂďůĞWĂƚĐŚ ϯ ϴ͕ϱϰϬ͛Eͬϯ͘ϱϬ͟/W ϭϭͬϭϳͬϭϳ WZ&KZdKEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &ƚ ĂƚĞ ^ƚĂƚƵƐ dϲ ϱ͕ϭϱϬ͛ϱ͕ϭϳϱ͛ϰ͕Ϭϳϰ͛ϰ͕Ϭϵϴ͛Ϯϱ ϯͬϰͬϭϳ /ƐŽůĂƚĞĚ dϳ ϱ͕ϯϯϯ͛ϱ͕ϯϱϯ͛ϰ͕ϮϱϬ͛ϰ͕Ϯϲϵ͛ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϴ ϱ͕ϯϳϮ͛ϱ͕ϯϵϮ͛ϰ͕Ϯϴϴ͛ϰ͕ϯϬϳ͛ϮϬ ϯͬϰͬϭϳ KƉĞŶ dϭϰ ϲ͕Ϭϲϳ͛ϲ͕ϬϴϮ͛ϰ͕ϵϳϱ͛ϰ͕ϵϵϬ͛ϭϱ ϯͬϮͬϭϳ KƉĞŶ dϭϳ ϲ͕ϯϬϲ͛ϲ͕ϯϮϲ͛ϱ͕Ϯϭϯ͛ϱ͕Ϯϯϯ͛ϮϬ ϯͬϮͬϭϳ KƉĞŶ dϰϯ ϲ͕ϴϲϭ͛ϲ͕ϴϳϬ͛ϱ͕ϳϲϴ͛ϱ͕ϳϳϳ͛ϵ ϯͬϯͬϭϳ KƉĞŶ dϴϭ ϳ͕ϴϮϰ͛ϳ͕ϴϯϯ͛ϲ͕ϳϯϭ͛ϲ͕ϳϰϬ͛ϵ ϯͬϮͬϭϳ KƉĞŶ dϴϯ ϳ͕ϴϲϯ͛ϳ͕ϴϳϵ͛ϲ͕ϳϳϬ͛ϲ͕ϳϴϲ͛ϭϲ ϯͬϭͬϭϳ KƉĞŶ dϴϯ ϳ͕ϴϴϴ͛ϳ͕ϴϵϲ͛ϲ͕ϳϵϱ͛ϲ͕ϴϬϯ͛ϴ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϭϯ͛ϴ͕Ϭϯϯ͛ϲ͕ϵϮϬ͛ϲ͕ϵϰϬ͛ϮϬ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϰϱ͛ϴ͕Ϭϲϱ͛ϲ͕ϵϱϮ͛ϲ͕ϵϳϮ͛ϮϬ ϯͬϭͬϭϳ KƉĞŶ dϵϬ ϴ͕Ϭϳϴ͛ϴ͕ϭϭϬ ϲ͕ϵϴϱ͛ϳ͕Ϭϭϳ͛ϯϮ ϮͬϮϴͬϭϳ KƉĞŶ dϵϬ ϴ͕ϭϰϴ͛ϴ͕ϭϲϴ͛ϳ͕Ϭϰϳ͛ϳ͕Ϭϳϱ͛Ϯϴ ϮͬϮϴͬϭϳ KƉĞŶ dϭϰϬ ϴ͕ϱϲϲ͛ϴ͕ϱϵϲ͛ϳ͕ϰϳϯ͛ϳ͕ϱϬϯ͛ϯϬ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ dϭϰϬ ϴ͕ϲϭϴ͛ϴ͕ϲϯϭ͛ϳ͕ϱϮϱ͛ϳ͕ϱϯϴ͛ϭϯ ϮͬϮϴͬϭϳ /ƐŽůĂƚĞĚ DEd d/>^ 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ĐŚĞĐŬƐ͘ ϳ͘Ϳ WůĂĐĞ ƐŝŐŶƐ ĂŶĚ ƉůĂĐĂƌĚƐ ǁĂƌŶŝŶŐ ŽĨ ŚŝŐŚ ƉƌĞƐƐƵƌĞ ĂŶĚ ŶŝƚƌŽŐĞŶ ŽƉĞƌĂƚŝŽŶƐ Ăƚ ĂƌĞĂƐ ǁŚĞƌĞ EŝƚƌŽŐĞŶŵĂǇĂĐĐƵŵƵůĂƚĞŽƌďĞƌĞůĞĂƐĞĚ͘ ϴ͘Ϳ WůĂĐĞ ƉƌĞƐƐƵƌĞŐĂƵŐĞƐĚŽǁŶƐƚƌĞĂŵŽĨůŝƋƵŝĚĂŶĚŶŝƚƌŽŐĞŶƉƵŵƉƐƚŽĂĚĞƋƵĂƚĞůǇŵĞĂƐƵƌĞƚƵďŝŶŐ ĂŶĚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐ͘ ϵ͘Ϳ WůĂĐĞ ƉƌĞƐƐƵƌĞŐĂƵŐĞƐƵƉƐƚƌĞĂŵĂŶĚĚŽǁŶƐƚƌĞĂŵŽĨĂŶǇĐŚĞĐŬǀĂůǀĞƐ͘ ϭϬ͘Ϳ tĞůůƐŝƚĞ DĂŶĂŐĞƌƐŚĂůůǁĂůŬ ĚŽǁŶǀĂůǀĞĂůŝŐŶŵĞŶƚƐĂŶĚĞŶƐƵƌĞǀĂůǀĞƉŽƐŝƚŝŽŶŝƐĐŽƌƌĞĐƚ͘ ϭϭ͘Ϳ ŶƐƵƌĞ ƉŽƌƚĂďůĞϰͲŐĂƐĚĞƚĞĐƚŝŽŶĞƋƵŝƉŵĞŶƚŝƐŽŶƐŝƚĞ͕ĐĂůŝďƌĂƚĞĚ͕ĂŶĚďƵŵƉƚĞƐƚĞĚƉƌŽƉĞƌůǇƚŽ ĚĞƚĞĐƚ>>ͬ,Ϯ^ͬKϮͬKϮůĞǀĞůƐ͘ŶƐƵƌĞEŝƚƌŽŐĞŶǀĞŶĚŽƌ ŚĂƐĂǁŽƌŬŝŶŐĂŶĚĐĂůŝďƌĂƚĞĚĚĞƚĞĐƚŽƌĂƐ ǁĞůůƚŚĂƚŵĞĂƐƵƌĞƐKϮůĞǀĞůƐ͘ ϭϮ͘Ϳ WƌĞƐƐƵƌĞ ƚĞƐƚůŝŶĞƐƵƉƐƚƌĞĂŵŽĨǁĞůůƚŽĂƉƉƌŽǀĞĚƐƵŶĚƌǇƉƌĞƐƐƵƌĞŽƌDW^W;DĂǆŝŵƵŵWŽƚĞŶƚŝĂů ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞͿ͕ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘dĞƐƚůŝŶĞƐĚŽǁŶƐƚƌĞĂŵŽĨǁĞůů;ĨƌŽŵǁĞůůƚŽƌĞƚƵƌŶƐ ƚĂŶŬͿ ƚŽϭ͕ϱϬϬƉƐŝ͘WĞƌĨŽƌŵǀŝƐƵĂůŝŶƐƉĞĐƚŝŽŶĨŽƌĂŶǇůĞĂŬƐ͘ ϭϯ͘Ϳ ůĞĞĚ ŽĨĨƚĞƐƚƉƌĞƐƐƵƌĞĂŶĚƉƌĞƉĂƌĞĨŽƌƉƵŵƉŝŶŐŶŝƚƌŽŐĞŶ͘ ϭϰ͘Ϳ WƵŵƉ ŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϱ͘Ϳ tŚĞŶ ĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵ EŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ ĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚ EŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞ ǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶ ƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞ ũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞ DĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDK EŝƚƌŽŐĞŶWƵŵƉŝŶŐ hŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ 410 • 216132 28 789 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 RECEIVED Tele: 907 777-8308 Nitrnrp Ind.._LLG Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED itA/2011 NOV 1 3 2017 K.BENDER DATE 11/11/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCANNED FEB 0 1 ZOi8 Kalotsa 1 Prints and data DEFT-PFCS-PILS-PGMC-PBMS CD: Final Well Data Hilcorp KALOTSA_1 PPROF 050CT17 FINAL 10/10/2017 12:42 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: ✓��a o_goceezt Date: • of 7.4 • • `6.s I//jy SA THE STATE Alaska Oil and Gas 9� Of � Conservation Commission- � AL � __=-- � St�x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager . .. 1 2 Hilcorp Alaska, Inc. ' ., 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 1 Permit to Drill Number: 216-132 Sundry Number: 317-526 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this (3 day of November, 2017. !L- i .:'1 I 1, 2017 RECEIVED • STATE OF ALASKA NOV 0 3 201? ALASKA OIL AND GAS CONSERVATION COMMISSION jarT'S i 6I /3 ( L7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations Q • Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: CT Jet 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Ng Hilcorp Alaska,LLC Exploratory ❑ Development D• 216-132 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20657-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O 701A Kalotsa 1 • Will planned perforations require a spacing exception? Yes ❑ No 2 9.Property Designation(Lease Number): 10.Field/Pool(s): C061505(SHL),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): 8,866' • 7,773' • 8,617 7,524' 1,571 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,509' 7-5/8" 1,509' 1,360' 6,890psi 4,790psi Intermediate Production 8,846' 4-1/2" 8,846' 7,499' 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 1,300'MD/1,212'TVD;N/A;N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Stratigraphic ❑ Development 2 Service ❑ 14. Estimated Date for 15.Well Status after proposed work: CommencingOperations: November 17,2017 • OIL WINJWDSPL P ❑ El El Suspended ❑ 16.Verbal Approval: Date: GAS 0 • WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Ted Kramer-777-8420 Email tkramera_hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature �� Phone 907-777-8405 Date /1/3/17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: C-,,--- 1�1. 5� IP Plug Integrity ❑ BOP Test Iiii Mechanical Integrity Test ❑ Location Clearance 0 Other: _7 640& /1-5- 1-SCY) '—re---, ' CC-.r ) Post Initial Injection MIT Req'd? Yes ❑ No ❑ :3 L\-/ L-, ! <. L- 11' Spacing Exception Required? Yes ❑ No EI Subsequent Form Required: r 0 _- yOtt Kg::E--\' _ APPROVED BY '1 /13 i' AAL- Approved(bey: COMMISSIONER THE COMMISSION Date: ,`V /y/ �'' o RR I Submit Form and /\J Form 10-403 R ised 11/2015 �' Approved application is valid for TL nRrtI QINA ro I Attachments in Duplicate • • • Well Prognosis Well: Kalotsa#1 IIilcorp Alaska,LI) Date: 11/3/2017 Well Name: Kalotsa #1 API Number: 50-133-20657-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: November 17th, 2017 Rig: E-Line/CTU Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 216-132 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0662 (C) Second Call Engineer: Taylor Nasse (907)777-8354 (0) (907) 903-0341 (C) AFE Number: 1612639C Maximum Expected BHP: —2,241 psi @ 7,538' TVD (From RFT data.) Max. Potential Surface Pressure: — 1,571 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary Kalotsa #1 is a grass roots development well targeting gas sands in the Tyonek formation. This well reached TD on 12/30/16. The Well was perforated in ten sand packages and placed on production. It is now suspected that the bottom interval,the T-140 Sand is producing water. The purpose of this work/sundry is to set a CIBP over the top of the T-140 sand at 8,610' (+/-) to isolate water_ and then blow the well dry using coil tubing and nitrogen. The well will then be placed on production and a flowing pressure temperature log ran after 10 days to see if the fluid level has decreased. Notes Regarding Wellbore Condition • Well is producing. • A PLT log ran on 10-5-17 indicated a Fluid Level at 6,298 feet. r 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 Procedure E-line: 1. MIRU e-line and PT lubricator to 3,500 psi Hi 250 Low. t e 2. PU, RIH w/GR to 8,615'. POH. (Note: This step may be done ahead of time with Slick-line.) 3. PU, RIH W/4-1/2" CIBP to 8,610' (+/-). POOH. Coiled Tubing Procedure 4. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. • • • Well Prognosis Well: Kalotsa#1 Hilcorp Alaska,LU Date: 11/3/2017 5. RU N2 pumping unit. 6. PU, RIH with Nozzle to 8,610' and lightly tag CIBP. 7. Drop ball and come online with N2 and jet well dry. a. Estimated volume of Produced water to displace is 36 bbls. 8. POOH w/coil. LD BHA. 9. RD Coiled Tubing. 10. Turn well over to production. Attachments: 1. Actual and Proposed Schematic 2. Coil BOPE Schematic 3. CT Flow Diagrams(Forward and Reverse Jetting) 4. Wellhead Diagram i • Ninilchik . 11SCHEMATIC Well Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 Hileorp AI ka.LI.0 12KB=18' CASING DETAIL l6" L Size Type Wt Grade Conn. ID Top Btm 16" Conductor-Driven to 84# X-56 Weld 15.01" Surf 120' Set Depth 7-5/8" SurfCsg 29.7# L-80 BTC 6.875" Surf 1,509' r r 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958" Surf 8,846' a JEWELRY DETAIL 1 No. Depth ID OD Item r;.:-'~ ' '' 1 1,300' 3.958" 6.875" Baker Swell Packer 7-5/8" iAIIIII = ` 1 PERFORATION DETAIL . r Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Size Date T6 5,150' 5,175' 4,074' 4,098' 25 2-7/8" 3/4/17 T7 5,333' 5,353' 4,250' 4,269' 20 2-7/8" 3/4/17 ' ' 7 s T8 5,372' 5,392' 4,288' 4,307' 20 2-7/8" 3/4/17 ' T14 6,067' 6,082' 4,975' 4,990' 15 2-7/8" 3/2/17 T17 6,306' 6,326' 5,213' 5,233' 20 2-7/8" 3/2/17 T42 6,861' 6,870' 5,768' 5,777' 9 2-7/8" 3/3/17 T80 7,824' 7,833' 6,731' 6,740' 9 2-7/8" 3/2/17 ' t, T83 7,863' 7,879' 6,770' 6,786' 16 2-7/8" 3/1/17 T83 7,888' 7,896' 6,795' 6,803' 8 2-7/8" 3/1/17 T6 T90 8,013' 8,033' 6,920' 6,940' 20 2-7/8" 3/1/17 T90 8,045' 8,065' 6,952' 6,972' 20 2-7/8" 3/1/17 T90 8,078' 8,110 6,985' 7,017' 32 2-7/8" 2/28/17 T7 T90 8,148' 8,168' 7,047' 7,075' 28 2-7/8" 2/28/17 T140 8,566' 8,596' 7,473' 7,503' 30 2-7/8" 2/28/17 T8 T140 8,618' 8,631' 7,525' 7,538' 13 2-7/8" 2/28/17 i T14 (ii, T17 r T42 T80 - T83 T90 4-1/2" ' . - T140 PBTD=8,704'/PBTVD=7,611' TD=8,866'/TVD=7,773' Updated by DMA 11-03-17 • • • Ninilchik • H PROPOSED SCHEMATIC Well Kalotsa #1 PTD: 216-132 API: 50-133-20657-00-00 Hilrorp Alaska,LLC RKB=18' CASING DETAIL r Size Type Wt Grade Conn. ID Top Btm 16" Conductor-Driven to 16" Set Depth 84# X-56 Weld 15.01" Surf 120' " ., 7-5/8" Surf Csg 29.7# L-80 BTC 6.875" Surf 1,509' r 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958" Surf 8,846' JEWELRY DETAIL No. Depth ID OD Item 1,, kp. 1 1,300' 3.958" 6.875" Baker Swell Packer 7-5/8 -' 1 2 ±8,610' CIBP PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Size Date T6 5,150' • 5,175' 4,074' 4,098' 25 2-7/8" 3/4/17 T7 5,333' • 5,353' 4,250' 4,269' 20 2-7/8" 3/4/17 r, T8 5,372' • 5,392' 4,288' 4,307' 20 2-7/8" 3/4/17 T14 6,067' • 6,082' 4,975' 4,990' 15 2-7/8" 3/2/17 T17 6,306' • 6,326' 5,213' 5,233' 20 2-7/8" 3/2/17 T42 6,861' • 6,870' 5,768' 5,777' 9 2-7/8" 3/3/17 T80 7,824' • 7,833' 6,731' 6,740' 9 2-7/8" 3/2/17 T83 7,863' • 7,879' 6,770' 6,786' 16 2-7/8" 3/1/17 T83 7,888' • 7,896' 6,795' 6,803' 8 2-7/8" 3/1/17 ty,,..4%,, 4 T6 T90 8,013' ' 8,033' 6,920' 6,940' 20 2-7/8" 3/1/17 °. ; T90 8,045' 8,065' 6,952' 6,972' 20 2-7/8" 3/1/17 190 8,078' 8,110 6,985' 7,017' 32 2-7/8" 2/28/17 4 T7 190 8,148' 8,168' 7,047 7,075' 28 2-7/8" 2/28/17 T140 8,566' I 8,596' 7,473' 7,503' 30 2-7/8" 2/28/17 $ ' • T8 T140 8,618' • 8,631' 7,525' 7,538' 13 2-7/8" 2/28/17 ; r T14 ,44 T17 y �{ T42 k,,,,_=.„.41;Lit, T80 T83 a , ..s T90 T140 4-1/2" PBTD=8,704'/PBTVD=7,611' TD=8,866'/TVD=7,773' Updated by DMA 11-03-17 1111 • Ninilchik Field II Kalotsa 1 10/31/2017 Hik..rp ‘64111.1.11: .. a"mi"Ss- litiNk ., !__ . Iiiiirnr:::..:r N Halle _._ .I■w_r Bili I lu , Coiled Tubing HR580 Injector Head&Gooseneck 16I• ice![I Weight=12,850 lbs _ �.---.� trill • -4 4-1/16"10K Conventional Stripper Ih I'iI 16.441 5K C062 Lubricator Kill PnA WH PSI 6 1502 x 2-1/16 10K i.11. 2" - Flanged Valve VO 4 5K CO62 x 4-1/16"10K Flange (Manual) 2-1/16 10K x2-1/16 Ott,-, l�� 4-1/16"10K Combi BOP 10K Ranged Valvejh,iL� Top Set:Blind/Shear (Manual) JI_� 1®. 11'1%' / 4 Second Set:Pipe/Slip ctr 4-1/16"10K Flow Cross Manual 2x2 Valve t 2"1502 x 2-1/16"10K Flange 010/14104.11[001010 4.;1[001010 Manual 2x2 Valve 2:2-1/16"10K x2-1/16"10K Flange Manual 2x2 Valve 3:2-1/16"10K x2-1/16"10K Flange Manual 2x2 Valve 4:2"1502 x 2-1/16"10K Flange I♦ 4 4-1/16"10K x Wellhead Adapter Flange 401=oII��ll■ Vt.: -4 Wellhead • • (n LII F QY ]] U c., cn 9 ' J m 0 Q Y , 7 : - '7 o Z Y E o w k +' s e`55 co v, liii o Y�4S 4 a e N • • Z O O Li c o C • A o d O F— 1 1 I 4-9. 0 iiii illll Illi 7 11111/1111 0 III■II■N;",Il1111.,IVV, 111 N A ' 1111 Iiii iii IHI S .; 1f w it ' V Z _y L c F- 0 d 0 F- C 1 c O Wm O A110 I 0 I • r________ :3 i8 It a 11 \ ..11 !/ ._ c of C C 12 O o a OV N Z Oit 8 0 t 11 5 i . • •• g : g3 • s ¢ 1CD v < t ,3 ZN 9 3 mo8 ,] � L_ g '7 F O p s • U Z Q epeVI Se N ggtt • s = • A p o • 8 1111 i A E Vi ►• N Z cn o E U v Z cu 0 CCd o I11I 1111 III 1111 i "M ..L, t illi 0 III■II■II'4'11111M'Il' 1i4 il'n' 1111 1111 1111 IIII S - •- w ig ; '!_____. -.., A t v D. 0 1- 1 E /■ v 8- R • e V •A 04,11 7-- -----., . 0 i o i 8 ti c it a c -o 0 n . °' V N o Z 0 q1 We 0 O p i • 0 111 Ninilchik Unit Kalotsa #1 and #2 10/30/2017 If tkorp Maxim,LU: Ninilchik Unit Casing hanger,CW,11 x4 Kalotsa#1 and 2 DWC/C box btm x 6.125"RH 16 x 7 5/8 x 4'A stub acme box top,w/7 5/8 od neck,4"type H BPV profile,DD-NL material BHTA,Otis,41/16 5M FE x 6.5 Otis quick union top za Va lye,Swab,WKM-M 1 4 1/16 5M FE,HWO, EE trim l,,-.. Valve,Wing,WKM-M, 3 1/S 5M FE,HWO, Valve,Wing,SSV,WKM-M, EE trim 3 1/8 5M FE,w/15"Hydraulic operator .; ,a fit+ it \ Valve,Upper master, WKM-M, `g i 4 1/16 5M FE,HWO,EE trim -...- (O O !... LLL!.. u Valve,Master,WKM-M, *`'r-c' 41/16 SM FE,HWO, EE trim (�"� tom.. l . ......._.__.__.._...-.. ' 1 Tubing head,Cactus C-29L- HPS,135/85Mx115M,w/ — �--ilF ' 2-2 1/16 SM SSO o r { i 0 o 1 — Starting head,Cactus C-29L, -1— 1 j —%—r-_3 135/85M x16 SOW,w/2-2 � 1/165M SSO " ir , Ij I 1 16' ___... 7 5/8'• 4/" • • STANDARD WELL PROCEDURE IlikorpAlaska,l.li: 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/1-12S/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 FINAL v1 Page 1 of 1 III • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la.Test: LJ Initial U Annual U Special lb.Type Test: U Stabilized Li Non Stabilized ❑ Multipoint 0 Constant Time ❑ Isochronai ❑ Other: 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska,LLC 03/18/17 216-132 3.Address: 6.Date TD Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 12/29/16 50-133-20657-00 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 2200'FSL,446'FWL,Sec.7 TIS R13W,SM,AK 144.5' Kalotsa 1 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 878'FNL,1517'FEL,Sec 12,T1 S,R14W,SM,AK 8,704'MD/7,611'TVD Ninilchik Field Total Depth: 9.Total Depth(MD+ND): Beluga/Tyonek Gas Pool 748'FNL,1651'FEL,Sec 12,T1 S,R14W,SM,AK 8,866'MD/7,773'TVD 4b.Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15,Property Designation: Surface: x- 209844 y-2233473 Zone- 4 N/A (SHL)C061505/(TPH/BHL)ADL384372 TPI: x- 207935 y-2235637 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 207805 y-2235771 Zone- 4 4-1/2"Production String,Perforated 17,Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 4-1/2" 12.6# 3.958" 8,846' 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. 5,150'-5,175' 6,861'-6,326' 8,450'-8,065' 5,333'-5,353' 7,824'-7,833' 8,078'-8,110' 5,372'-5,392' 7,863'-7,879' 8,148'-8,168' 6,067'-6,082' 7,888'-7,896' 8,566'-8,596' N/A 'SCANNED `!/\ 1 2 2A13 6,306'-6,326' 8,013'-8,033' 8,618'-8,631' 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 1,300' 0.56 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): 0 Tubing Q Casing 97 F° 2,700 psia @ Datum 6,096 TVDSS psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H25: Prover: Meter Run: Taps: 0.56 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. X 2. X 3. X 4. X 5. X - Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No, (24-Hour) h- Factor Factor Pm Fb or Fp Ft Fg Fpv Qi Mcfd 1. 2. 3. 4. 5. Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. 2. 3. Critical Pressure 4. Critical Temperature 5. Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDE Submit in Duplicate RBDMS Uu SEP - 6 2017 • • Pc Pc2 Pf Pf2 No. Pt pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Pse Pf-Ps2 2. 3. 4. 5. 25. AOF (Mcfd) 14,325 Remarks: I hereby certify that the- -9•ing is true and correct to the best of my knowledge. Signed Title Reservoir Engineer Date 09/06/17 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producin face were reduced to zero psia Fb Basic orifice factor Mcfd/ PhVv m Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 1(Z mensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas(air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil(60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L,feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope)of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H,psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd(14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. 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Q I m l6 U E 'p -°O Ili , E co N £ E 0 2 a) Q a 0 o a 0 0 0 a 0 0 21 6132 •eth Nolan Hilcorp Alaska,�CLC °' 8 GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Aileurprtb.hkw,iu: RECEIVED Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED -i it22o1 JUL 0 7 2017 K. BENDER DATE 07/07/2017 A®GCC To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Kalotsa 1 Prints and data CBL-VDL-GR-CCL PNL-GR-CCL CD: Final Well Data Hiloorp Kalotsal FAST-SCMT 9Feb17 FINAL. 6/23/2(1711:16 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: • • Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday,June 19, 2017 3:18 PM To: Cody Dinger Cc: Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: Kalotsa 1, PTD 216-132, CBL missing Hello Cody, I am completing the compliance review on Kalotsa 1, PTD 216-132,completed March 18, 2017. On May 3, 2017,Guy Schwartz requested from Taylor Nasse an electronic copy of the CBL and that the CBL was not indicated on the 10-407 form.A paper log and electronic copy of the CBL has not yet been submitted to the AOGCC, as required. Please supply the electronic and paper CBL by June 28, 2017. Please send the log data to my attention. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 • • 216132 Seth Nolan Hilcorp Alaska, LLC 2 8 1 6 5 GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 H�Is�rp:l14e4a,I.*A: RECEIVED Fax: 907 777-8510 DATA LOGGED E-mail: snolan@hilcorp.com s iti2o1Z MAY 0 5 2017 M.K.BENDER DATE 03/31/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Kalotsa 1 Prints and data Prints Production Profile CD: Final Well Data DCIS Data 6MMCF 3/31/2017 2:02 PM File folder .j, DLIS Data 12MMCF 3/31/2017 2:02 PM File folder LAS Data 6MMCF 3/31/2017 204 PM File folder LAS Data 1214MCF 3/31/2017 203 PM File folder 34 Log 3/31/2017 204 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: RECEIVED • STATE OF ALASKA • A 11 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDAnACC 1 a.Well Status: Oil ❑ Gas❑✓ • SPLUG ❑ Other p Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aban... 3/18/2017 ' 216-132/317-069 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 December 16,2016 . 50-133-20657-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2200'FSL,446'FWL,Sec 7,T1S, R13W,SM,AK • December 29,2016 Kalotsa 1 • Top of Productive Interval: 9. Ref Elevations: KB: 144.5 • 17. Field/Pool(s): 878'FNL, 1517'FEL,Sec 12,T1S, R14W,SM,AK GL: 126.5 BF: 124.5 Ninilchik Field/Beluga/Tyonek Gas Pool- Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 748'FNL, 1651'FEL,Sec 12,T1S, R14W,SM,AK , 8,704'MD/7,611'TVD . (SHL)C061505/(TPH/BHL)ADL384372 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 209844• y- 2233473 • Zone- 4 •8,866'MD/7,773'TVD • N/A TPI: x- 207935 y- 2235637 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 207805 y- 2235771 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 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 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 Log MD/TVD Final Well Report, ROP-EWR-ALD-CTN-DGR 5"/2"MD, EWR-ALD-CTN-DGR 5"/2"TVD, Production Profile ( j 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 84# X-56 Surface 120' Surface 120' Driven Driven 7-5/8" 29.7# L-80 Surface 1,509' Surface 1,361' 9-7/8" Lead-207 sx/Tail-126 sx 4-1/2" 12.6# L-80 Surface 8,846' Surface 7,753 6-3/4" Lead-752 sx/Tail-162 sx 24. Open to production or injection? Yes ❑✓ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4-1/2"Longstring Packer See Attached Perf Interval Sheet @ 1,300'MD/1,212'TVD 1.-'t't `"1 gr'`'' 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 . 11146 la Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 3/4/2017 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 3/24/2017 24 Test Period —♦0 12473.2 7.5 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 1180 0 24-Hour Rate ...+ 0 12473.5 • 7.5 N/A Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only 1,1 s yn �� s—/,i/7 RBDMS 'C'- APP 1 7 2017 ,,,'.: c rz.(-7 28.CORE DATA Conventional•(s): Yes ❑ No ❑✓ Sidewall Core•Yes ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes Q No ❑ Permafrost-Top N/A N/A If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval T6 Sand 5150 T6 Sand 4074 information, including reports, per 20 AAC 25.071. Top of Beluga 1,649 1,455 Top of Tyonek 4,658 3,627 T65 Sand 7,570 6,477 Well is currently flowing at—12.38 mmcfpd.See attached sheet for interval breakdown. Formation at total depth:T146 8842 7749 31. List of Attachments: Wellbore schematic, Drilling and Completion Reports, Definitive Directional Surveys,Casing and Cement Reports, Perforation Record, Days vs depth,MW vs Depth. 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. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Dinger Email: cdingerCc�hilcorp.com Printed Name: Cod Diner Title: Drilling Tech Signature: Phone: 777-8389 Date: 48// /Z a/?- 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 1 b: 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 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 11/2015 Submit ORIGINAL Only • • Ninilchik }vSCHEMATIC Well Kalotsa #1 / PTD: 216-132 API: 50-133-20657-00-00 Hilcorp Alaska,LLC r P RKB=18' �; 2.- • <-252' CASING DETAIL ., 'a Size Type Wt Grade Conn. ID Top Btm 16" 16" Conductor-Driven to 84# X-56 Weld 15.01" Surf 120' Set Depth .', i ,'d" l 7-5/8" Surf Csg 29.7# L-80 BTC 6.875" Surf 1,509' 1-. ` (fly 4-1/2" Prod Csg 12.6# L-80 DWC/C HT 3.958" Surf 8,846' • -,..-..„0"tr } J. I*' �` JEWELRY DETAIL ,.. - No. Depth ID OD Item a ` , 1 1,300' 3.958" 6.875" Baker Swell Packer tin7-5/8" ' -r 1 13°°' r., PERFORATION DETAIL 'F'''1%` "�, Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Size Date 1 ', .-' 16 5,150' i 5,175' 4,074' 4,098' 25 2-7/8" 3/4/17 '* :,* T7 5,333' * 5,353' 4,250' 4,269' 20 2-7/8" 3/4/17 r+ t; T8 5,372' • 5,392' 4,288' 4,307' 20 2-7/8" 3/4/17 T14 6,067' . 6,082' 4,975' 4,990' 15 2-7/8" 3/2/17 9e T17 6,306' r 6,326' 5,213' 5,233' 20 2-7/8" 3/2/17 + ' ,.4 T42 6,861' • 6,870' 5,768' 5,777' 9 2-7/8" 3/3/17 1 V: 41 T80 7,824' • 7,833' 6,731' 6,740' 9 2-7/8" 3/2/17 , 51 SSU T83 7,863' • 7,879' 6,770' 6,786' 16 2-7/8" 3/1/17 T6 T83 7,888' • 7,896' 6,795' 6,803' 8 2-7/8" 3/1/17 +' T90 8,013' . 8,033' 6,920' 6,940' 20 2-7/8" 3/1/17 T90 8,045' • 8,065' 6,952' 6,972' 20 2-7/8" 3/1/17 T90 8,078' • 8,110 6,985' 7,017' 32 2-7/8" 2/28/17 T7 T90 8,148' • 8,168' 7,047' 7,075' 28 2-7/8" 2/28/17 _ 1140 8,566' • 8,596' 7,473' 7,503' 30 2-7/8" 2/28/17 t -•- -'-,- T8 T140 8,618' • 8,631' 7,525' 7,538' 13 2-7/8" 2/28/17 T14 ',7' T17 r, T C T42 ,1.otA T80 7 14'`^f ` t . 1;1. 44 lii 1 T83 -t * . 4. T90 T90 0,71400 .7.3 4-1/2" �': T140 PBTD=8,704'/PBTVD=7,611' TD=8,866'/TVD=7,773' Updated by CJD 04-11-17 o • PERF INTERVAL (MD) PERF INTERVAL (TVD) INTERVAL NAME RATE (MMCFPD) 5150 5175 4074 4098 T6 0 5333 5353 4250 4269 T7 1.41 5372 5392 4288 4307 T8 0.56 6067 6082 4975 4990 T14 0.12 6306 6326 5213 5233 T17 6.6 6861 6870 5768 5777 T42 0 7824 7833 6731 6740 T80 3.73 7863 7879 6770 6786 T83 0 7888 7896 6795 6803 T83 0 8013 8033 6920 6940 T90 0 8045 8065 6952 6972 T90 0 8078 8110 6985 7017 T90 0 8148 8168 7055 7075 T90 0 8566 8596 7473 7503 T140 0 8618 8631 7525 7538 T140 0 • • Hilcorp Energy Company Composite Report Well Name: NINU Kalotsa 1 Field: Ninilchik County/State:Kenai,Alaska (LAT/LONG): avation(RKB): 18.3 API#:50-133-20657-00 Spud Date: 12/16/2016 Job Name: 1612639D Kalotsa 1 Drilling Contractor Saxon 169 AFE#: AFE:tafiii.fitiktiliERMINEMBEENSMOMMOMMESER:iiiiinaig$064WEREMISSEMENESESESSONSMINIMMEMEyX 12/7/2016 No activity.Peak crew and rig crew on location at 9:00.;Received pits 1-2 and 3.Peak offloaded same with crane and bed truck,staged pits on pad.Had AK West Express move empty trailers(6)off location.Rig crew and Peak hands layed out felt and liner,;then set rig mats.Received both pump skids and spotted same on pad.Welder installed cellar ladder,rig crew installed annulus valve on wellhead.We were notified there would be no more loads;arriving tonight. Released Peak and rig hands for the night.We have one Peak crane,bed truck and loader on location.Pits,pumps,poorboy degasser and gen 3 skid. Blizzard conditions.;No activity.Will be on location at 9:00 to cont receiving loads and cont RU. 12/8/2016 No activity,both rig crews and Peak on location at 9:00.;Received first truck at 9:00 and offloaded Drill side pony wall and rig mats.Receive and offload trailer of assorted equipment,offload doghouse and stage on pad,spot crane for setting sub base,;receive and offload offside pony wall,crew installed handrails and roof top lights while waiting on sub base,received and offload topdrive and accessories,offload HPU skid and carrier,large gen;skid,sub base arrived at 15:00 hrs,offload same and stage over well.Hoist sub base and set pony walls,center up over wellhead,set pit#1,fold out stairs and set handrails on sub base.;No activity.Will be on location at 9:00 to cont receiving loads and cont RU.Derrick is staged off pad. 12/9/2016 No activity.Peak crew, rig crew and three Lynden trucks on location at 9:00.;Offload Lynden trailers while spotting 2nd Peak crane to handle carrier.Set carrier on sub,set derrick on carrier.Set pits#1 and#2.Set HPU skid,set water tank and raise doghouse,set gen 1-2;skid,raise pit roofs and set landings, set iron roughneck on rig floor,set pit#3,set pumps#1 and#2,raise derrick board wind walls,string electric cables.Offloaded Saxon loader and windwalls.;Both crews worked until noon,night crew released to return at 18:00.;Set both boiler skids,cont stringing electric cords,start gen#1 and turn on the lights.Cont RU pit modules,offload Sperry shack,prep and raise derrick,start MU steam lines. 12/10/2016 Cont MU steam lines,cords etc between skids,level up doghouse/watertank,offload 45 jnts 4 1/2"DP,spot crane and set windwalls around rig floor and pits, offload mudlab,;receive and set break shack,office trailer,sleeper trailer and pushers trailer,lay out liner and set catwalk,remove brake bands from draw works drum,offload and set centrifuge,;backhaul 3 truckloads of rig mats to KGF.;String cords from sub to catwalk,replace brake bands on draw works, spooled drill line on drum,run Pason cords throughout the rig,spot gen 3 and service shacks,;work on stand pipe,received Saxon connex. 12/11/2016 CO pump#2 liners to 5 1/2",cont thawing various plumbing,CO boiler feed pumps,open up boiler#1 for cleaning,drive ground stakes,swap camp gen set out,;stage diverter equip behind rig,take on rig fuel,fill boiler#2 with water,offload lower torque tube section,scope derrick up,installed lower torque tube, install T bar;pull radiator on pump#2 for upper/lower oil pan gasket change,;Organize pad and get not needed tools and equipment ready for back haul, remove 5"liners from mud pump#1,rig up top drive,install bales and elevators.;fire up boiler#2 and get steam though out rig,prep rig for gas buster install. 12/12/2016 Stand and pin poorboy degasser vessel,install Handy Berm around entire rig and catwalk,ship out Peak crane and empty connex's,wire in service shacks(3), cover and heat catwalk,;cont working on steam in sub base and choke house,receive surface directional tools and sources,RU comm tower at Dionne pad and our location,tie in service shacks and office trailers to comm's,;install oil pan and radiator on pump#2 engine,build mud docks on edge of pad.;lnstall wind walls on mud pump#2,work on getting steam to rig floor,function rotary table,clean&organize rig floor,cont.to organize pad,work on rig acceptance check list. 12/13/2016 Strung out Geronimo line and anchor block,got water circulating throughout rig,shipped out excess rig mats,staged diverter"r and gun barrels behind rig, RU Pason in service shacks.;Changed oil in draw works motor,CO hopper suction gate valve rubbers,clean and organized tool room on rig floor,clean and organized pump rooms,function tested shakers,ran gen#3(OK).;RU Sperry monitor in doghouse.;Test run both mud pumps.Clean out ice from mud dock staging area.Nipple up diverter spacer,diverter T,nipple up diverter line and stage. Fill rig tank with H2O.Filling bulk tank at S.D.pad. f 12/14/2016 Held"pause"meeting with HSE Rep's Matt Hogge,Leonard Dickerson and both rig crews,received gel and bar products,4 bolted up knife valve and gun barrel,could not line up without running into sub;base or cat walk,will have to install a 22.5 deg bend in gun barrel.Welder altered grating and supports in11>t�c/ cellar box to accommodate spool flanges and welded bolts on boiler to button up door;(couple bolts broke off while flanging door back in place).Total Safety �4Lj RU gas detection equipment.Added 135 bbls water to pits 2-3-4 and ran charge pumps/gun lines(OK),RU Canrig logger equipment,;took on rig fuel,CO • agitator motor in pit#3,received 21 1/4"annular and jars from Weatherford.Notified AOGCC of upcoming diverter function test,went through rig acceptance checklist.;Accepted rig at 18:00 hrs.Cont NU diverter system,install and nipple up Saxon 21.25"annular,align and secure diverter line to anchor towers. Continue to roll water in pits,2,3,4.Install riser. 12/15/2016 Cont bolt up remaining diverter vent line,chain off stack 4 ways,adjust vac unit location for distance to end of vent line,Total Safety on location and CO control box for gas alarms,RU bleeder and;fill up lines,welder installed new bracket for mud line in pump room,function tested annular and knife valve numerous times with joint in hole,called out AOGCC Rep for 14:00 hrs,received HWDP,;test joint and wear ring. AOGCC Rep Bob Noble on location at 14:15 hrs. Started mixing spud mud per Mud Engineer.;lnspected and measured vent line,performed function test of diverter,performed koomey drawdown test.No issues or failures.Total Safety was on location and performed gas detection equip test.;Offload DP,rack and tally same for PU.CO saver sub.Mud Engineers, Drilling Foremen,Peak Drivers,Tool Push all participated in a Waste Manifest class given by Environmental Specialist Amy Peloza.;Prep to PU rack back 4 1/2"CDS 40 DP,installed wear ring,(12 7/16"ID)installed 4"ball valves on conductor outlet.;Pick up and rack back 48 joints 4'W'DP.Cover and warm centrifuge,complete building 250 bbls spud mud 200 vis.Haul in more drill pipe from storage pad.;Off load and strap 22 more joints of 4W DP.;Pick up and rack back remaining 22 joints.Tag bottom 112'from rig floor.35 stands stood back.2177.90'.Blow air through centrifuge,good.Patch hole in herculite spill containment.;Strap 9 joints 4W DP,stand back.;Mobilize BHA tools to rig floor,and pipe skate.Install MWD transducers on stand pipe,prepare 6"drill collar slips,dog collar.Fill lines,and hole,and conduct low pressure test of and lines. • • 12/16/2016 Cont staging BHA while troubleshooting Pason depth tracker.Prep corner of pad to rack surface casing.Set up depth tracking off MWD computer,Pason Rep enroute to rig.;MU 9.875"Smith MSI519 PDC bit and 7"Sperry motor w/1.5 degree bend.MU XO and 2 stands HWDP.Break circ at 350 gpm with no issues.;Tpa up at 112'and spud well.Drill from 112'to 245',wob 1-5K,350 gpm-520 psi,34 rpm-5800 ft/lbs on bott torque,then circulated hole clean.;Pull up hole from 245'to 27'racking back HWDP.Up wt 18K.Blew down topdrive.;PU DM collar and MU on motor,pull bit to floor and inspect(OK),RIH cont MU DGR,EWR-P4 and PWD collars.Orient toolface(RFO 228.53 degrees),MU topdrive warm up tools.;Plugged in and uploaded MWD.Pason Rep replaced UJB(universal junction box)in doghouse.;Cont PU BHA to 245'MD.;Kick off @ 245'MD.Directional drill from 245'to 291'.;Trip out one stand.Pick up jars and last HWDP single.;Directional drill 9.875"surface hole from 291'to 555'.1400 psi PP/10k Wob/50 Rpm.475 Gpm.;Directional drill 9.875"surface hole from 555'MD to 791'.1700 psi PP/10k Wob/50 Rpm.500 Gpm.;Circulate the hole clean.500 gpm-1700 psi.;Wiper trip to the top of the HWDP.Pulled forst stand and swabbing.Pumped out @ 3.3 Bpm to the flex collars.Hole in good shape.;Trip back to bottom.Wash last stand down.Hole in good shape.Had no fill on bottom.;Cont to directional drill 9.875"surface hole from 791'to 854'MD. 12/17/2016 Cont directional drilling 9 7/8"surface hole from 854'to 1518'.Rotating wob 9 to 14K,554 gpm-2236 psi,80 rpm-8600 ft/lbs on bolt torque,ROP 55 to 165 ft/hr,MW 9.2 ppg/vis 72,;ECD's 9.5 ppg,BGG 19 units.TD'd surface section at 1518',in sandstone.Had a max of 126 units gas at 1294'.Last survey at TD: 1481'md,47.24 deg Inc,320.05 deg Azi,1341'tvd.;Received 207 sx lead cement and cementing equipment as well as Weatherford casing equipment.;CBU x 2 while building sweep,pumped same at 553 gpm-1989 psi,and had 20%increase in cuttings to surface.No change in up/dwn weights after sweeping hole.;Pulled wiper trip,mad passing all slide intervals,from 1452'to 245'.While logging,pumped at 433 gpm-1181 psi,rotated at 30 rpm-3600 ft/lbs off bott torque.+/-370'logged.;Hole in good shape.All logging data acquired.Monitor well static.Calc=10.18 bbls,Actual hole fill=30 bbls.;Rig service.Grease and inspect crown/blocks,top drive,draw works,brake link.Inspect all pins and keepers.Change out TDS control board for motor.;Trip back in the hole on elevators.Wash down last stand.No fill,no hole drag.;Pump HI-Vis sweep surface to surface.30%increase of cuttings seen at shakers.Returned on time, gauge hole.530 Gpm,50 Rpm,1800 PP,4500 ft/lbs torque.MW=9.2,ECD=9.4.;POOH on elevators from 1518'to 1790.Rack back HWDP,lay down 6W Weatherford Hydraulic jars,one jt HWDP.;PJSM with DD/MWD/CoMan and crew.Time,distance and shielding safety topic regarding nuclear sources. Retrieve sources.down load MWD data. 12/18/2016 Cont download MWD tools.Weatherford on location checking their equipment.LD remaining BHA,bit graded at 2-6-BT-G-X-I-CT-TD.;Clean and clear rig floor,PU test joint and run tool,pulled wear ring,SLB arrived with cement trucks and tail cement.PU landing joint/hanger and dummy ran same.;RU Weatherford casing equipment and held PJSM with rig team and casing crew.;PU and MU shoe track with no issues,filled pipe and checked float equipment i( (OK).Cont PU TIH with a total of 36 jnts+20'pup,7 5/8",29.7#,L-80 surface casing.;Filled pipe on the fly and filled completely every 10 joints.PU landing jnt 4t�f and hanger,MU and landed same with no issues.MU circ swedge and topdrive.;Broke circ at 140 gpm-42 psi getting good returns,worked string 10'.Up wt 45K,dwn wt 30K.Increased rate to 200 gpm-57 psi.RU SLB cementers while RD Weatherford.;Down pump,break off topdrive and circ swedge.blew dwn S�r q" topdrive.Load plugs and MU cement head on landing jnt.Held PJSM with rig team,cementers and Peak drivers.Prime cement pump.;MU plug launcher and GS/ hardline,SLB loaded lines with 2 bbls water and checked for leaks.SLB pressure tested lines at 1600 low 3800 high,good tests.Rig pumped 23 bbls 10 ppg MudPush II at 3.3 bpm;and shut down.SLB dropped bottom plug and pumped 89.6 bbls(207 sx)12 ppg Class A lead cement at 4.8 bpm,followed by 27.4 bbls (126 sx)15.4 ppg Class A tail cement at 4.8 bpm.SLB dropped top plug;then displaced with 67 bbls 9.2 ppg Spud Mud at 4.8 bpm,500 psi.Slowed to 2 bpm " with 5 bbl to go.Bumped the plug,and held 1025 psi(FCP of 550 psi)for 3 minutes,bled off and floats held.;Bled back 1/2 bbl to truck.Had 23 bbls MudPush A ?, II return to surface and 20 bbls of good 12 ppg lead cement to surface.We also added cemnet to both lead and tail cement at 1/4 ppb.Mix water temp at;82 deg.Pumped 50%excess on both lead and tail.Attempted to reciprocate the string throughout the job,but after installing cement head string would not move. Up wt 45K,dwn wt 30K at time of;landing hanger.Had no losses.With MudPush to surface diverted remaining returns to cellar box through 4"outlet.CIP at 22:15 hrs,12-18-16.;RD,cleaned up and released Schlumberger(off location @ 2400 hrs).Cleaned out cellar box.Prepped to install packoff assembly.;Back out landing joint from hanger,wash top of hanger,picked up packoff and made up to landing joint,ran in the packoff with Wellhead hand.Landed,ran in and tightened all lock downs.;Nipple down diverter line,knife valve,annular.;Hauled 72 bbls cuttings to KGF G&I.Cumulative 342 bbls. Hauled 273 bbls class 2 fluids to KGF G&I.Cumulative 273 bbls. Hauled 40 bbls cement returns to KGF G&I.Cumulative 40 bbls. No DH losses 12/19/2016 Finish ND annular,DSA's and spacer spool.Stage all three on matting and pressure wash.Remove items from sub base.Haul water to pits for building mud. Stage BOP cradle.;MU"B"section on wellhead.Tested packoff at 500 psi and 3000 psi,good tests.Shipped out 13"wear ring/run tool,received 11"wear ring/run tool.Start building KCL mud.;Spot Peak crane and raise BOP stack on cradle.Fly BOP stack to end of sub and swap to BOP trolly's.Roll crane off location,trolly BOP's into sub base.;NU HCR valves on stack,studs on bottom of single gate were damaged,replace same, ship out Weatherford annular and casing equipment.Load and stage diverter equipment on Bad pad.;Total safety on location at 14:00 hrs and calibrated/tested gas detection equipment (good).Install inside choke,inside kill.Nipple up choke line to choke house.Continue to nipple up BOPE.;Continue to nipple up BOPE.Hammer up choke line. Fluid block on choke valve,Install hydraulic fittings in single gate ram.Install hydraulic fittings of double gate ram.;lnstall lines to annular.Rig up accumulator lines,install riser to flow box,rig up poor boy gas buster return line.Function test BOP components.Install chain and binders.;Rig up air lines,test pump and P hoses.Completed building 520 bbls of KCL mud.Lay down riser for repair,damaged 2"collars.;Open casing valve.Make up test plug/test joint.Set plug. Q,.`b Make up FOSV and dart valve to test joint.Fill stack with water.;Perform shell test.Flood choke manifold.Pressure up choke to 1000 psi.Bleed out air.Begin i test.Test#1:UPR's,Choke man valves 1,3,4,5,7,Mezzanine kill valve,dart,Hyd IBOP,250/3500 10 mins;Hauled 18 bbls cuttings to KGF G&l. Cumulative=360 bbls. Hauled 217 bbls.Class 2 junk fluid to KGF G&I.Cumulative=490 bbls. Hauled 0 cement.Cumulative 40 bbls. No down hole losses to date. 12/20/2016 Continue testing BOPE 250/3500 10 minutes each test. Fail/Pass-annular and LPR. Bled off and functioned twice. Retested-good. Accumulator draw down starting pressure 3000 psi,;final pressure 1425 psi,1st 200 psi recharge=17 seconds,final 87 seconds.(4)N2 bottles at 2600 psi average. Right to witness waived by Jim Regg.;Pull test plug and rig up and test 7-5/8"casing to 3500 psi for 30 minutes-good.;Install 9"wear bushing.;Repair fill up line on bell nipple and install.;Strap and tally 198 joints pick up 15 singles drill pipe.Crew change.;Pick up 25 more singles.40 in the hole.;Service rig.Adjust brakes to increase tripping speed.Good.;Stand back 20 stands.4W CDS 40 DP.;Pick up 40 singles,run in the hole.41/2"CDS 40.;Move 4 stands of HWDP from Drillers side to ODS.;POOH rack back 20 more stands of 4'W'CDS 40 DP.;Single in 160 joints and stand back in batches of 40.115 stands in the derrick.;Hauled 0 bbls cuttings to KGF.360 bbls hauled to date. Hauled 0 bbls junk fluid to KGF.490 bbls hauled to date. Hauled 0 bbls cement to KGF.40 bbls hauled to date. No down hole losses on the well. i • 12/21/2016 Continue picking up and standing back drill pipe. Total of 115 stands in the derrick.;Clean and clear rig floor, Stage BHA components. Prep to pickup BHA.;Make up BHA as per detail;6-3/4 MM65D PDC bit,4-3/4 Motor with 1.5 bend,Integral blade,DM collar,PWD Collar,Stabilizer,slim phase-4,Stab,ALD Collar,CTN Collar TM collar. Shallow pulse test,;load sources. Continue M/U BHA(2)flex collars,XO,(2)HWDP,Jars,(7)HWDP. RFO:Motor to MWD 1.84"/4.82"=137.42.;Single in the hole to 1,117'.;Circulate annular volume to warm up mud and condition any potential cement contaminated fluid.;Continue to ' single in the hole to 1,356'. Wash down at 225 gpm/1190 psi,30 rpms 5Kft-lbs free torque. Tag up on cement at I,403.;Drill cement with WOB 0-3K,225 if gpm/1290 psi and 100 psi differential 30 rpms/5400 ft-lbs down to 1,422 observe torque spike to 5900 ft-lbs and increase in differential(1st plug)observe rubber over;the shakers at bottoms up. Continue drilling ahead varying parameters to drill up 2nd plug. Tag up at shoe at 1,507'(on depth). Drill rat hole and 20'of new hole to 1,538'.;Circulate and condition the hole for the FIT.Prejob safety meeting in the doghouse with crew for rig up to test.;Rig up and perform FIT to 14.3 ppq EMW.Current MW=9.2 TVD=1360.Achieved 360 psi.No fracture observed.Rig down test lines from test pump.Line up to pump down cn hole.;Circulate prejob meeting with Peak/Rig crew and Mud man.Displace to 6%KCL.PHPA mud.;Displace well to 9 ppg 6%KCL.120 bbls pumped 120 •3 t bbls returned.Shut down to clean under shakers.;Clean shakers,change screens to 140's.Clean possum belly,clean pit#4.;Complete the cleaning tasks in the pits.Secure shakers.Ready to drill.;Directional drill from 1538'MD.to 1927'MD.280 gpm,85 rpm,1200 psi on,1000 psi off,5k torque,5 to 10k wob,9.3 ppg clean hole ECD.9.94 ppg @ 140'/hr. 37k up 33k do 35k rot weights.;Directional position:6.2'high,6.06'right of plan.;Hauled 9 bbls cuttings to KGF.369 bbls hauled to date. Hauled 171 bbls junk fluid to KGF.661 bbls hauled to date. Hauled 0 bbls cement to KGF.40 bbls hauled to date. No down hole losses 12/22/2016 Continue drilling 6-3/4"hole from 1927'MD to 2,482'.300 gpm 1500 psi/150 diff,WOB 3-5K,80 rpm's 6500-7000 ft-lbs of torque. MW 9.1 ppg ECD's 10.2- 10.6 ppg EMW.;Observe gas spikes between 130-160 units at 1,942',2,264',2,420',and 2,481'.;Pumped hi vis sweep;20%increase in returns,circulate hole clean 3 hole volumes at 300 gpm 1300 psi 80 rpms 6000 ft-lbs of torque. ECD's decrease from 10.6 ppg to 10.2 ppg. Flow check well,static;Wiper trip up from 2,482'PUW 52K to 1,487'. No issues.;Service rig. Grease drawworks blocks,crown,and check brakes.;RIH from 1,487'to 2,482'washing the last stand , down. No fill encountered,no issues during trip.;Continue drilling ahead from 2482 t 2995'MD.300 Gpm,85 Rpm,1600 psi PP,7400 ft/lbs on,6500 ft/lbs off. ECD=10.48 average.Ream each stand,Mad pass slides.Running 15 bbls/hr water 9.15 Ppg MW.;Up weight 58k I Dn weight 43k/Rot Weight 46k.;Directional drill from 2995'to 3358'MD.Pumped sweep @ 2995'24 bbl Hi-Vis,50%increase in cuttings load.300 Gpm,85 Rpm,1650 PP,7k Wob, 120/hr.BHA building 0.7°per hundred in rotary.;Wellbore position:1'High,4'right of plan.Pumped a Hi-Vis nut plug sweep @ 3108,20%increase in cuttings.ECD average 10.55.;Hauled 108 bbls cuttings to KGF.477 bbls hauled to date. Hauled 162 bbls junk fluid to KGF.823 bbls hauled to date. Hauled 0 bbls cement to KGF.40 bbls hauled to date. No down hole losses 12/23/2016 Continue drilling ahead from 3358'to 3481'ROP 120 fph,300 gpm 1750 psi/210 differential;80 rpm's/7700 ft-lbs. WOB 3-5K,MW 9.2 ppg ECD 10.75 ppg EMW.;Pump high vis sweep(20%increase)and circulate hole clean(2.5 x annular volume)at 300 gpm 1600 psi. Flow check well-static,blow down top drive.;Wiper trip;POOH from 3,481'(PUW 72K)to 2,412'. Tight spots noted at:2819'-2809'25K over wipe clean;2764'-2760'25K over wipe clean;2708'- 2678'(slide depth)25K over wipe clean;and;2579-2552'(slide depth)30K over attempt to wipe clean unable to,ream clean while circulating annular volume. 270 gpm/1200 psi,40 rpms/7000 ft-lbs,ROTW 40K. Pull through tight spot-clean.;Service brakes and top drive.;RIH from 2,412'to 3,481'with no issues,no fill noted on bottom. Wash last stand to bottom.;Pump high viscosity sweep(30%increase).Continue drilling 6-314"fr 3,481'to 3851';ROP 120-150 fph,WOB 4-7K,300 gpm 1800 psi,80 rpms 8800 ft-lbs. MW 9.1 ppg,ECD 10.6-10.7 MAD pass all slides.;Directional drill from 3851'to 4228'.ROP 120-150'/hr,300 gpm,85 rpms,1800 pp on bottom 1600 pp off.9.1 ppg in/9.2 ppg out.ECD=10.64 ave.Weights,86k up,52k down,61k rot.Run 25 bph water.;Directional drill from 4228'to 4476'.ROP 120-150'/hr,300 gpm,85 rpms,1700 pp on bottom 1500 pp off.9.2 ppg in/9.2 ppg out.ECD=10.64 ave.Weights,90k up,54k down, 65k rot.Run 25 bph water.;Pump sweep surface to surface.Hi-Vis,nut plug,condet,30%excess returns.CBU one more time to clean up shakers.;Begin short trip.1000 foot trip planned.Wellbore position:2'low,4'left of plan.;Hauled 90 bbls cuttings to KGF.567 bbls hauled to date. Hauled 370 bbls junk fluid to KGF.1193 bbls hauled to date. Hauled 0 bbls cement to KGF.40 bbls hauled to date. No down hole losses 12/24/2016 Continue circulating hole clean,flow check well, blow down top drive.;Wiper trip. POOH to 3,416'. Tight spots noted at 3763'and 3653'with 30K over pull. Wipe once and ensure clean. Hole took 1.8 bbls over calculated.;RIH from 3,416'to 4,476'with no issues and no fill. Wash down last stand.;Pump high viscosity sweep(20%increase)and continue drilling 6-3/4"hole from 4,476'to 4970'. Sliding as need to drop 2°/100';MAD passing all slide.ROT 85 rpms/11000ft-lbs,303 gpm 1721 psi with;122 psi differential,WOB 5-7K. PUW 98K,SOW 58K,ROTW 66K. Pump high viscosity sweep at 4927'with 20% increase in cuttings.;Drilling 6-3/4"hole from 4970'to 5285'. Sliding as need to drop 2°/100';MAD pass slide intervals..ROT 85 rpms/10600 ft-lbs,303 gpm 1800 psi wi 200 psi differential,WOB 5-9K.;340 units max gas @ 5270'MD.ECD 10.6 ppg,MW 9.15 out,9.1 ppg in.Running 10 bph water.Strap and tally first 150 joints 4.5"liner.280 bbls heated water ready.;Drilling 6-3/4"hole from 5285'to 5470'. Sliding 10'of each stand to drop 2°/100';MAD pass slide intervals. ROT 85 rpms/10600ft-lbs,303 gpm 1800 psi wi 200 psi differential,WOB 5-9K.;Up wt=127k/Dn Wt=62k/Rot Wt=80k:Wellbore position 2.8 feet low.0.85 feet left of plan.;Pump sweep surface to surface.40%excess returns seen at shakers.CBU 2 x's.SPR's.Monitor well.Start short trip.;Pull clean from 5470 to 4800'MD.Good hole fill.No drag seen.Crew change.;Hauled 67 bbls cuttings to KGF.634 bbls hauled to date. Hauled 293 bbls junk fluid to KGF.1486 bbls hauled to date. Hauled 0 bbls cement to KGF.40 bbls hauled to date. No down hole losses 12/25/2016 Continue with wiper trip;POOH to 4,482'. Observed tight spots at 4,810',4732',4670'at 20K over wipe x1 clean. 30-35K over at 4,622',4584',4,507'attempt to wipe clean multiple times attempt to;pump through at 4,622'still pulling 30K over. Back ream tight spots(4,622',4,584',4507')at 300 gpm/1634 psi 80 rpms with erratic torque from 9,000 ft-lbs to 12,500 ft-lbs.Pull through clean.;Continue POOH from 4482'to 3311'with intermittent 5K drag and 10-12K bobbles. At 3311'begin noticing tight spots with 25-40K over pull without breaking over at:3311,3253,3212,3150,3088'.;Back ream tight spots at 300 gpm, 80 rpms with erratic torque from 8-13 Kft-lbs. Pull through with no issues. Continue back reaming from 3,088'to 2,615'.POOH on elevators to 2279',35K overpull.;Pump high viscosity sweep(40%increase in cuttings)and circulate hole clean-3 annular volumes at 300 gpm/1300 psi 80 rpms/6700 ft- Ibs.;Continue POOH from 2,279'to 1,496'with no issues.;Service draw works,top drive and blocks.;RIH from 1,496'to 5,346'with no issues. Fill pipe and empty trip tank every 20 stands.;Reamed the last stand down with full drilling rates.300 gpm,80 rpm,Tag fill @ 5461'.Clean out to bottom,back ream stand. Level derrick,SPR's.1)541 psi @ 48 spm,2)513 psi @ 48 spm.;Up weight before trip was 128k,record 125k,down weight before trip was 60k,record 66k. Gained 9k of hole drag back.Before trip ECD=10.55 ppg,after ECD=10.28ppg.;Drilling 6-3/4"hole from 5470'to 5718'. Sliding 10'of each stand to drop 2°/100';MAD pass slide intervals..ROT 85 rpmsI10600ft-lbs,303 gpm 1900 psi wi 200 psi dif.Up 132k,Dn 70k,Rot 86k;Pumped 24 bbl Hi-Vis sweep with 3 sacks nut plug,and 8 gallons condet.30%increase in cuttings seen.Sweep came back 400 strokes late.Indicating a 15%to 20%open hole wash out factor.;Drilling 6-3/4"hole from 5718'to 6031'. Sliding 15'of each stand to drop 2°/100';MAD pass slide intervals..ROT 85 rpms/11,800ft-lbs,303 gpm 1900 psi wi 200 psi dif.Up 132k,Dn 70k,Rot 86k.;Hauled 18 bbls cuttings to KGF.652 bbls hauled to date. Hauled 162 bbls junk fluid to KGF.1648 bbls hauled to date. Hauled 0 bbls cement to KGF.40 bbls hauled to date. No down hole losses;Wellbore position:0.84'High,0.60'Left of plan. Sweep pumped at 5920 saw 40%increase in cuttings load. • 12/26/2016 Drilling 6-3/4"hole from 6031'to 6466'.2°drop section finished at 6,105',slide as needed to maintain course. MAD Pass all slide. ROP 100-150 fph,WOB 5- 8 K 80 rpms/13600 ft-Ibs,;303 gpm/1950 psi. MW 9.2 ppg ECD's 10.34ppg EMW. Gas spike of 400 units at 6342',100 units at:6092',6192',6229', 6466'.;Circulate high viscosity sweep(20%increase)and clean hole(3 x annular volume).;Wiper trip:POOH from 6466'to 5441'(PUW 170,SOW 78K)with no issues. Hole took 1.87bbls over calculated.RIH to 6,466'with no issues wash last stand to bottom no fill.Calculated displacement.;48 units of trip gas.;Pump high viscosity sweep(40%increase in cuttings),and continue drilling to 6,500'at 303 gpm 2018 psi,82 rpms/12800 torque,WOB 8K. MW 9.2 ppg ECD's 10.32 ppg EMW.;Drilling 6-3/4"hole from 6500'to 6853'. Vertical wellbore,minimal slides.(0.85 inclination).ROT 85 rpms/13500ft-lbs,303 gpm,2050 psi w/300 psi dif.Up 170k,Dn 80k,Rot 100k.;Drilling 6-3/4"hole from 6853'to 6970'.(0.66 inclination).ROT 85 rpms/13500ft-lbs,303 gpm,2050 psi w/300 psi dif.Up 170k,Dn 80k,Rot 100k.Driller saw high torque,notified CoMan.;Rack back one stand,to readjust top drive high torque setting from 15k to 18.6k ft/lbs.While screwing into stump with top drive,top drive grabber leg weld broke on off driller side.;Establish full circulation.Assemble tools needed to take apart broken'Grabber Leg:,rotate slow,drill string free,good pump pressure.Shut down rotary to allow rig crew to work. Take piece off.;Details:Remove grabber leg,unbolt Driller side that was not sheared.Disconnect HYD IBOP line,install bail link tilt bolts.Mechanic and Electrician travel to Kenai to retrieve new equipment.;Establish full flow,and rotary.Ream stand.Set slips and adjust internal top drive max torque setting up to 18,600 ft/lbs from 15,000 ftllbs.;Make connection,slow ream to bottom,resume drilling from 6970 to 6976.ROT 80 rpms/13500ft-lbs,303 gpm,1950 psi w/180 psi dif.;Hauled 63 bbls cuttings to KGF.715 bbls hauled to date. Hauled 387 bbls junk fluid to KGF.2035 bbls hauled to date. Hauled 0 bbls cement to KGF.40 bbls hauled to date. No down hole losses;Wellbore position:15.36 feet distance to plan.14.51'high,5.05'right. 12/27/2016 Continue drilling from 6976 to 7,027'ROP 60 fpm at 80 rpms/13800 ft-lbs,303 gpm/2000 psi,WOB 8-9K,MW 9.2 ppg,ECD 10.56 ppg EMW.;Pump sweep and circulate hole clean.;POOH to 6,902'-good sand formation. Install new grabber box while circulated at 140 gpm 650 psi.;Rig service,grease TD and drawworks. Function test IBOP.;RIH with no fill or issues to 7027'and continue drilling to 7463'with minimal maintenance slides. ROP 100-150 fph,WOB 7- 9K,302 gpm/2267 psi,80 rpms/13800 ft-lbs torque. MW 9.2 ppg.;ECD's 10.6 ppg EMW. Observe gas spikes of 100 units at 7,204',150 units 7212',170 units at 7273',7426'.;Pump high viscosity sweep(20%increase)and circulate hole clean 3 annular volumes at 300 gpm/1950 psi,80 rpms/13600 ft-lbs. Flow check,Blow down top drive.;Wiper trip,POOH from 7,463'to 6,464'with no issues,displacement 0.23 bbls over calculated.(Functioned annular,upper and lower pipe rams).;RIH from 6,464'to 7,400'with no issues.;Wash and ream last stand to bottom from 7,400'to 7,463',no fill on bottom.Circulate B/U with 303 gpm.3280 units max gas on B/U.;Drill ahead from 7,463'to 7,527',PU 195 K,SO 84 K,ROT 115 K,80 RPM,Torq 14/15 K ftllbs,10 K WOB, 50-75 ROP, 302 GPM,2150 PSI,9.25 PPG Mud Wt,10.5 PPG ECD.;Drill ahead from 7,527'to 7,850',PU 200 K,SO 90 K,ROT 115 K,80 RPM,Torq 15/16 K ft/lbs,10 K WOB, 50-75 ROP,302 GPM,2250 PSI,9.25 PPG Mud Wt,10.55 PPG ECD 12/28/2016 Drill ahead from 7,850'to 8,329',PU 200 K,SO 92 K,ROT 118 K,80 RPM,Trq 15/16 K ftllbs,10 K WOB, 50-75 ROP,303 GPM,2298 PSI,9.3 PPG Mud Wt,Add 0.25%NXS to assist weight transfer to bit.;Lost rotary on top drive. Troubleshoot,no rotary or link-tilt. Continue circulating and working pipe. 37-pin on top drive had come loose. Secure pin.;Drill ahead from 8,329'to 8,617',PU 200 K,SO 94 K,ROT 117 K,80 RPM,Trq 16.5 K Wlbs,10 K WOB, 50 ROP, 303 GPM,2350 PSI,9.3 PPG Mud Wt,10.6 PPG ECD,Back reaming each stand.;Drill ahead from 8,617'to 8,676'.Encountering high torque and stalling top drive.;Pump NXS sweep and work through high torque section.Observed 10%increase in cuttings.;Drill ahead from 8,617 to 8,833',PU 205 K,SO 98 K,ROT 115 K,80 RPM,Trq 16.5 K ft/lbs,10 K WOB, 50-70 ROP,303 GPM,2450 PSI,9.3 PPG Mud Wt,10.62 PPG ECD,Back reaming each stand. 12/29/2016 Drill ahead from 8,833 to 8,866'(TD), 80 RPM,Trq 17.2 K ft/lbs,10 K WOB, 50-70 ROP,303 GPM,2450 PSI,9.3 PPG Mud Wt,10.62 PPG ECD,Back reaming each stand.;Pump high viscosity sweep(10%increase in cuttings,15 bbls late). Circulate hole clean(2 hole volumes)at 300 gpm 2200 psi,80 rpms 17KWIbs,reciprocating pipe. Flow check well,static.;Wiper trip to shoe. POOH to 4891'tight spots noted at 7668'with 30K without breaking over(Stabilizer at coal)ream with pumps at idle and 30 rpms,and pull through on elevators. 35-40K over;without breaking at 5395'and 5331'back ream at 140 gpm/700 psi, 40 rpms and erratic torque from 9K-16Kft-lbs. Wipe through clean. Continue POOH,tight spots of 40K over at 4891',4835',4781';(every stand)not breaking over. Back ream from 4900'to 4417'at 303 gpm 1800 psi/60 rpms and erratic torque from 8K-18K ft-lbs. Torque not erratic from 4473'-4415'.;*note from 5470'-4476'has only been wiped through once;in 2°/100 drop.;Pump high viscosity sweep(20%increase)and circulate 2 hole volumes with sticky clay observed over the shakers. 303 gpm/1735 psi,60 rpms/8500 ft-lbs of torque.;Continue to POOH to 2283'with no issues.;Pump high viscosity sweep(30% increase)and circulate hole clean with BHA out of shoe. 303 gpm/1554 psi 60 rpms/6000 ft-lbs.;POOH to from 2283'to 1,494'with no issues.;Service rig: grease blocks,TD,DW,crown. Inspect brakes.;RIH with no problems from 1,494'to 6,469'.;Circ B/U and circ out gas with 300 GPM, 1950 PSI,60 RPM,12 K TRQ,2014 max units of gas.;RIH from 6,469'to 8,361'.Tight hole @ 8,361'with 15 K WOB.;Attempt to work tight hole with 40 K max over pull.No success. Attempt to rotate and rotate free with 30 RPM @ 16 K TRQ.Attempt to work pipe without rotation with no success.;break circ with 3 BPM @ 900 psi and rotate 30 RPM @ 16 K TRQ.Work pipe free.BROOH partial stand from 8,361'to 8,337'.POOH from 8,337 to 8,214'.;Circ and cond hole with 250 GPM,1600 PSI, 60 RPM,14-15 K TRQ.30%increase in cuttings on B/U.;RIH from 8,214'to 8,341'.Wash and ream tight spots to 8,394'with 200 GPM,1200 PSI,30 RPM, 16 K TRQ. 12/30/2016 Continue working tight spots from 8361'(bit and stab at coal)to 8460'gently reaming at 30 rpms 14,500 ft-lbs to 18,000 ft-lbs;140-200 gpms 840-1200 psi. Continue running in hole from 8460'to;8866'(TD)with no issues.;Pump high viscosity sweep and circulate hole clean while weighing mud system up to 9.5ppg for hole stability.;POOH to above troublesome coal(8361').;Lay down 8 stands of drill pipe to 8048',and circulate hole-maintain 9.5 ppg in/out.;RIH from 8,048'to 8432'with no issues.;POOH with drilling assembly,laying down drill pipe from 8432'to 1,488'.;Perform well control drill.;POOH with drilling assembly, laying down drill pipe from 1,488'to 492'.;RIH remaining 5 stands of drill pipe in derrick from 492'to 807'.;POOH with drilling assembly,laying down drill pipe from 807'to 492'.;UD 6 3/4"drilling BHA from 492'to 120'.PJSM on sources.Remove sources and up-load data from MWD.Cont.to UD BHA. 12/31/2016 Continue to UD BHA and Bit. Bit grade 1-2-CT-G-X-I-NA-TD.;Pull wear bushing. Dummy run casing hanger and mark landing joint;Rig up to RIH with casing. Change out bails,stage centralizers on rig floor. Rig up Weatherford tongs and slips.;M/U shoe track and baker lock. Check floats(good). RIH with 4-1/2 DWC/C casing to 1,470'(surface shoe).;Circulate and condition hole. Stage pumps up to 5.2 bpm,360 psi. Circulate 1 annular volume.;Continue to RIH with 4-1/2"DWC/C casing from 1,470'to 3,790'.;Circulate hole clean staging pumps up to 7 bpm, 240 psi,circulate 2 annular volumes.PU wt 45 K,SO wt 32 K.;Continue to RIH with 4-1/2"DWC/C casing from 3,790'to 6,428'.;Circulate hole clean staging pumps up to 5 bpm, 350 psi,circulate 1 annular volume.PU wt 80 K,SO wt 50 K.;Continue to RIH with 4-1/2"DWC/C casing from 6,428'and land on hanger @ 8,846'(Overall no issues running casing,worked thru 1 tight spot @ 8,370').;Break circulation and stage pumps up to 6 bpm,930 psi.Condition mud for cement job. 1/1/2017 Continue circulate and condition mud for cement job at 6 bpm,930 psi.;Rig up cement head,hook up lines. Prep for cement job.;Line up to break circulation prior to cement job. Due to a communication error Mud Push from pit system was pumped away.;Wait on mud push additive from SLB warehouse in Nikiski. Continue circulating Mud Push out of hole.;Build mud push for cement job.;Pump cement as per detail. Flood lines with water and PT cement lines to 4500 psi 14111 -good. Pump 23.5 bbls 10.9ppg mud push,drop plug,pump 226.5 bbls 13.5 ppg Lead cement,38.8 bbls 15.3 ppq tail:cement.drop plug,displace with 10 bbls water followed by 124 bbls 8.7 ppg KCL brine. Did not bump the plug,22 bbls lost during cement job. Cement returns seen at surface.;14 bbls ,, contaminate cement returns seen at surface.;Lead cement pumped at 5.2 bpm ICP 800 psi,FCP 306 psi,tail cement pumped at 4.9-5.5 bpm ICP 579 psi, 1A041 FCP 760 psi. Displacement pumped at 6 bpm ICP 1551 psi,FCP 2600 psi. Slow pump rate to 1 bpm;to bump plug. Did not bump the plug. Check floats-1 bbls returned. Floats held. CIP at 14:41.;Rig down cementing equipment. Flush BOP stack with black water.;lnstall packoff assembly.;Rig down floor equipment,casing bails elevators,rig tongs.Slip and cut drill line.Clean pits.Service mud pumps.;Cont.to clean pits and service mud pumps.prep for rig move.;Attempt to test casing with landing joint. Pressure bleeding off and fluid leaking through landing joint seals.UD landing joint.;Flood lines through HCR kill line.Close blind rams and test casing to 3500 psi for 30 min(good test.)Bleed off pressure.;Set BPV.N/D BOPE. • • 1/2/2017 N/D BOPE. Remove flow line. Lift stack and pull spacer spools. Clean pits.;N/U abandonment tree. Test hanger seals and packoff void 500/5000 psi for 5/15 minute. Good. Continue cleaning pits.;Pull BPV,suck out casing and freeze protect with diesel to 30'. Set BPV and install cap.;Continue cleaning pits,rig down mud pumps. Load out BOP. R/D TD. Remove wind walls. R/D HPU and load out third party shacks. Rig on move rate.;L/D top drive.L/D gas buster. Hook up bridle lines.L/D fingers.Remove turn buckles.Un-plug crown.top section lights,and prep to scope un-scope derrick.Perform derrick inspection.;Blow down boilers.Un-scope derrick.L/D derrick.Prep pad for herculiner and mat boards. • • 11 Hilcorp Energy Company Composite Report Well Name: NINU Kalotsa 1 w Field: Ninilchik County/State: Kenai,Alaska (LAT/LONG): `) �< ?Nation(RKB): API#: 50-133-20657-00 "( � top D Spud Job Name: 1612639C Kalotsa 1 Completion Contractor AFE#: AFE$: Aetrui3y#�at� *5 SuFrrmarY tM`?'>` m : `::: ' 2/4/2017 SLB called and had a radiator hose bust in town.Waited on SLB,PTW and JSA.Spot equipment and rig up lubricator. PT to 250 psi and 3500 psi high.,RIH w/SLB RST/SCMT log,tie into LWD log dated 29-Dec-16 and tag TOC at 8617. Log out of hole to surface at 30 FPM.,Rig down lubricator and turn well over to field.Will be logging Kalotsa#2 Monday due to not having a SLB crew.SLB will be sending log to Taylor, Dan and Jacob. (o� 2/22/2017 PTW and JSA.Spot up coil equip. Rig up coil tubing. Fill supply tank with 280 bbls water. Pressure Test coil BOP rams and valves to 250 psi low and 4500 psi high. Had trouble with fluid going by swab valve and master during test.Cycled the valves a few times and valves held.AOGCC waived witness.,SDFN. Will MIT the IA in the morning and chart on SLB recorder ry gauge p= � p � � »JDsi for MIT.Unload 10 bbls 2l23/2017� PTW,JSA and SIMOPS with construction.. Send crystal au a to Kenai Gas.Hook u Field tri lex and ressure IA u to 2500 _ +V methanol into SLB tank. Haul another load of water in vac truck(350 bbls total). Place in ground heater in supply tank. Put heater on coil and heater still on well head.Finish rig up.Got another load of water.We have approx.350 bbls water in tank.,Took approx.350 gals of methanol to fill back side. Bring 8 bbls methanol out to use as spear for coil tubing.Got everything ready to start milling cement in the morning. 2/24/2017 PTW,JSA and SIMOPS.Warm up equipment. Re-do MIT on the IA. Pull test coil connection to 30,000 lbs and PT 4500 psi.MU Weatherford 3.80"mill and motor.Sent MIT chart to town.,RIH with 1-3/4"coil tubing and mill assy and tag cement at 8690'coil tubing KB(20').Call town and discussed.E-line had tagged up at 8617'correlated. Decided to mill 43'or until we saw pieces of rubber from plug,First 5'milled off with hardly any motor action.Started milling e about 1/2'per min at 1.9 bpm/4200 psi to 8704'and got rubber up from returns.Called town and decided to go ahead,and circulate bottoms up and then blow well dry with N2. Drop cir sub ball and hit at 30 bbls and sheared at 3300 psi.,Circulate bottoms up.Bring_N2 on line at 2000 scf per min at 3100 psi and started out of hole and after unloading 110 bbls got N2 back and cut rate back to 1500 psi until N2 pressure was 1600 psi that was left on well. Had vac truck drop load of water at G&I.Got back a total of 135 bbls counting coil displacement.,Break Weatherford mill and motor off coil and set injector back.Secure well. Used 1600 gals N2.Moving to Kalotsa#2 in am. 2/28/2017 PTW and JSA.Spot equip and rig up lub. PT to 250 psi low and 3500 psi high.TP-1550 psi,RIH w/2-7/8"x13'HC Razor,6 spf,60 deg phase and tie into CBL. log dated 4-Feb17.Tag TOC at 8710'.Run correlation CCL/GR log and send to town.Get ok to perf from 8618'to 8631'.Spotted and fired shot with 1550 psi and after 5 min pressure no change. POOH.All shots fired and gun was wet.,RIH w/2-7/8"x30'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4- Feb17. Run correlation CCL log and send to town.Get ok to perf from 8566"to 8596'.Spotted and fired shot with 1583 psi,went to 1586 psi and after 5 min pressure 1591 psi. POOH.All shots fired and gun was wet. Lost tool wt at 8250'which could have been fluid level.,RIH w/2-7/8"x20'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17. Run correlation CCL/GR log and send to town.Get ok to perf from 8148'to 8168'.Spotted and fired shot with 1603 psi,and after 5 min pressure 1594 psi. POOH. .All shots fired,gun was Dry and TP is down to 1538 psi.Lost tool wt at 8180'which could be fluid level.,RIH • w/2-7/8"x32'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17.Run correlation CCL log and send to town.Get ok to pert from 8078'to 8110". Spotted and fired shot with 1530 psi,and after 5 min pressure 1522 psi. POOH. .All shots fired,gun had trace of water in bull pl}ag and TP is down to 1508 psi,Rig down lubricator and lay down crane due to wind.Secure well and SDFN.Will cont in the AM. 3/1/2017 PTW and JSA.Spot equip and rig up lub. PT to 250 psi low and 3500 psi high.TP-1402 psi,Ran GPT tool to and found fluid level at 7855'with tubing pressure 1402 psi. Decided to cut back length of pert guns to 20'max.POOH,RIH w/2-7/8"x20'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4- Feb17. Run correlation CCL log and send to town.Get ok to pert from 8045'to 8065'.Spotted and fired shot with 1430 psi,and after 5 min pressure 1431 psi. POOH. .All shots fired,gun was Wet.,RIH w/2-7/8"x20'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17. Run correlation CCL log and send to town.Get ok to pert from 8013'to 8033'.Spotted and fired shot with 1425 psi,and after 5 min pressure 1426 psi. POOH. .All shots fired,gun was Wet.,RIH • w/2-7/8"x33'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17.Run correlation CCL log and send to town.Get ok to pert from 7888'to 7896'- 9'spacer-from 7863'to 7879'. Fired gun with 1415 psi on tubing and 1516 psi after 5 min. POOH.Gun wet,all shots fired.,RIH with GPT tool and find fluid level at 7730'with 1414 psi on well.Send log to town.,Rig down lubricator and SDFN 3/2/2017 PTW and JSA. Rig up lub and PT 250 psi and 3500 psi high.TP-1482 psi,RIH w/2-7/8"x9'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4- Feb17. Run correlation CCL log and send to town.Get ok to perf from 7824'to 7833'.Spotted and fired shot with 1482 psi,and after 5 min pressure 1710 psi., 10 min-1915 psi, 15 min-2068 psi,20 min-2208 psi and 25 min-2253 psi.2313 psi at surface with gun POOH.All shots fired,gun was dry.2398 psi,RIH w/2-718"x9'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17. Run correlation CCL log and send to town.Get ok to pert from 6861'to 6870'. Spotted and fired shot with 2483 psi,and after 5 min pressure dropped to 2479 psi. POOH. .All shots fired,gun was dry,RIH w/2-7/8"x20'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17. Run correlation CCL log and send to town.Get ok to pert from 6306'to 6326'.Spotted and fired shot with 2445 psi,and after 5 min pressure dropped to 2390 psi. POOH.All shots fired,gun was dry,RIH w/2-718"x15'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17. Run correlation CCL log and send to town.Get ok to pelf from 6067'to 6082'.Spotted and fired shot with 2339 psi,and after 5 min pressure to 2340 psi. POOH. .All shots fired,gun was dry.,Ran GPT tool and found fluid level at 8080'at 2350 psi.,Rig down lub and SDFN 3/3/2017 PTW and JSA. PT to 250 psi and 3500 psi high.TP-2273 psi,RIH w/2-7/8"x18'HC Razor,6 spf,60 deg phase and tie into CBL log dated 4-Feb17. Run correlation CCL log and send to town.Town called back and said to come out of hole and run GPT tool. POOH,RIH w/GPT tool to 8700'. Logged up to 4600'. Found fluid level at 8100'.Sent log to town. POOH.Will perforate the T42 sand again.,RIH w/2-7/8"x9'HC Razor,6 spf,60 deg phase and tie into OHC. Run correlation CCL log and send to town.Get ok to pert from 6861 to 6870'. Fired gun with 2276'.After 5 min 2286 psi. POOH.Allhots fired.Gun was dry.,Rig down lubricator and moved crane to Kalotsa 2. • • 3/4/2017 PTW and JSA. Rig lub back up.PT to 250 psi low and 3500 psi high.TP-2330 psi,RIH w/2-7/8"x20'HC Razor,6 spf,60 deg phase and tie into OHC.Run correlation CCL log and send to town.Get ok to perf from 5372'to 5392'.Fired gun with 2330 psi.After 5 min 2310 psi.POOH.All shots fired.Gun was dry.,RIH w/2-7/8"x20'HC Razor,6 spf,60 deg phase and tie into OHC. Run correlation CCL log and send to town.Get ok to perf from 5333'to 5353'. Fired gun with 2320 psi,dropped to 2310 psi.and after 5 min 2292 psi.POOH.All shots fired.Gun was dry.TP-2273 psi.Field is also taking some gas for equipment.,RIH w/2-7/8"x25'HC Razor,6 spf,60 deg phase and tie into OHC.Run correlation CCL log and send to town.Get ok to perf from 5150'to 5175'. Fired gun with 2260 psi.After 5 min 2199 psi.POOH.All shots fired.Gun was dry. Field has been pulling some gas out well during the day so don't know how _good the readings are..,Riq down lubricator and turn well over to field. 3/17/2017 PTW and JSA.Spot and rig up lubricator.MU PLT tools on line and check,PT to 250 psi low and 3500 psi high.,RIH with SLB PLT tools and tie into SLB CBL log dated 4-Feb17.Well flowing 12.2 million at 1181 psi.Logged from 5100'to 8700'and back up at 80 fpm, 120 fpm and 180 fpm.They Re-logged an 80 fpm down and a 120 fpm down and up. Logged 16 five minute stops 8700',8614',8560.8144'.8076',8042',8010',7886',7860',7820',6854',6296',6057',5363', 5328',and 5130'.POOH.Had some ice and grease like stuff on spinner,Fluid level is 7840',Rig down lubricator and SDFN.Field will cut rate back to 6 million tonight and will be back in AM to run PLT at that rate. 3/18/2017 PTW and JSA.Spot and rig up lubricator.MU PLT tools on line and check,PT to 250 psi low and 3500 psi high. 6.2 million rate at 1638.7 psi,RIH with SLB PLT tools and tie into SLB CBL log dated 4-Feb17.Well flowing 6.08 million at 1610 psi.Logged from 5100'to 8700'and back up at 80 fpm,120 fpm and 180 fpm. Logged 16 five minute stops 8700',8614',8560.8144'.8076',8042',8010',7886',7860',7820',6854',6296',6057',5363',5328',and 5130'. Re-did up and down runs at 80 and 120.Also took one at 6329'.POOH.No water unloaded from,well while rate was between 6.0 million to 6.258 million and pressure between 1638.7 and 1644.1 psi.Fluid level is 7820'.,Rig down lubricator,turn well back over to the field and finish rig down. • ! Hilcorp Alaska, LLC Ninilchik Unit } Kalotsa Kalotsa 1 50-133-20657-00-00 Sperry Drilling Definitive Survey Report 03 January, 2017 HALLIBURTON Sperry Drilling • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Kalotsa 1 Project: Ninilchik Unit TVD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 1 wp04 @ 144.50usft ' Well: Kalotsa 1 North Reference: True Wellbore: Kalotsa 1 Survey Calculation Method: Minimum Curvature Design: Kalotsa 1 Database: Sperry EDM-NORTH US+CANADA Project Ninilchik Unit Map System: US State Plane 1927(Exact solution) I System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) . Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Kalotsa 1 Well Position +N/-S 0.00 usft Northing: 2,233,473.90 usft • Latitude: 60 6'14.861 N +E/-W 0.00 usft Easting: 209,844.16 usft • Longitude: 151°35'24.501 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: .126.50 usft Wellbore Kalotsa 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength I (°) (°) (nT) BGGM2016 12/13/2016 15.81 73.12 55,199 Design Kalotsa 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 317.21 Survey Program Date 1/3/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 195.22 1,481.69 MWD+SC+sag(1)(Kalotsa 1) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 12/06/2016 1,511.89 8,824.04 MWD+SC+sag(2)(Kalotsa 1) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 12/22/2016 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -126.50 0.00 0.00 2,233,473.90 209,844.16 0.00 0.00 UNDEFINED 195.22 0.28 275.72 195.22 50.72 0.04 -0.43 2,233,473.95 209,843.73 0.16 0.32 MWD+SC+sag(1) 263.52 2.31 315.25 263.50 119.00 1.04 -1.57 2,233,474.97 209,842.62 3.08 1.83 MWD+SC+sag(1) 325.10 4.83 319.69 324.95 180.45 3.90 -4.12 2,233,477.89 209,840.14 4.11 5.66 MWD+SC+sag(1) 386.70 7.73 317.80 386.18 241.68 8.94 -8.58 2,233,483.05 209,835.80 4.72 12.39 MWD+SC+sag(1) 447.98 10.78 315.94 446.65 302.15 16.12 -15.33 2,233,490.38 209,829.22 5.00 22.24 MWD+SC+sag(1) 510.80 13.60 315.10 508.05 363.55 25.57 -24.63 2,233,500.06 209,820.15 4.50 35.50 MWD+SC+sag(1) 573.09 16.00 315.15 568.27 423.77 36.85 -35.86 2,233,511.60 209,809.20 3.85 51.40 MWD+SC+sag(1) 633.10 18.09 314.45 625.64 481.14 49.24 -48.35 2,233,524.28 209,797.01 3.50 68.97 MWD+SC+sag(1) 695.70 20.05 314.84 684.80 540.30 63.61 -62.89 2,233,539.00 209,782.82 3.14 89.41 MWD+SC+sag(1) 757.81 21.40 314.97 742.89 598.39 79.13 -78.46 2,233,554.89 209,767.63 2.17 111.37 MWD+SC+sag(1) 821.49 23.57 316.58 801.73 657.23 96.59 -95.43 2,233,572.75 209,751.08 3.54 135.71 MWD+SC+sag(1) 883.95 24.41 316.45 858.79 714.29 115.01 -112.91 2,233,591.59 209,734.05 1.35 161.10 MWD+SC+sag(1) 1/3/2017 4:04:43PM Page 2 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Kalotsa 1 Project: Ninilchik Unit TVD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 1 wp04 @ 144.50usft Well: Kalotsa 1 North Reference: True Wellbore: Kalotsa 1 Survey Calculation Method: Minimum Curvature Design: Kalotsa 1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 947.79 25.60 316.49 916.65 772.15 134.58 -131.49 2,233,611.60 209,715.94 1.86 188.08 MWD+SC+sag(1) 1,010.08 27.33 316.77 972.41 827.91 154.76 -150.55 2,233,632.23 209,697.37 2.78 215.84 MWD+SC+sag(1) 1,073.01 30.20 317.73 1,027.57 883.07 177.00 -171.10 2,233,654.96 209,677.37 4.62 246.12 MWD+SC+sag(1) 1,136.26 33.54 318.52 1,081.27 936.77 201.87 -193.38 2,233,680.36 209,655.69 5.32 279.51 MWD+SC+sag(1) 1,198.36 36.45 319.23 1,132.14 987.64 228.70 -216.79 2,233,707.75 209,632.93 4.73 315.10 MWD+SC+sag(1) 1,262.27 38.76 319.11 1,182.77 1,038.27 258.20 -242.29 2,233,737.86 209,608.15 3.62 354.08 MWD+SC+sag(1) 1,324.77 41.81 319.76 1,230.44 1,085.94 288.90 -268.56 2,233,769.18 209,582.63 4.93 394.45 MWD+SC+sag(1) 1,386.41 44.61 319.69 1,275.36 1,130.86 321.10 -295.84 2,233,802.02 209,556.13 4.54 436.61 MWD+SC+sag(1) 1,448.31 46.17 319.98 1,318.83 1,174.33 354.78 -324.26 2,233,836.37 209,528.53 2.54 480.63 MWD+SC+sag(1) 1,481.69 47.24 320.05 1,341.72 1,197.22 373.39 -339.88 2,233,855.36 209,513.37 3.21 504.89 MWD+SC+sag(1) 1,511.89 47.92 320.30 1,362.10 1,217.60 390.51 -354.15 2,233,872.82 209,499.51 2.33 527.16 MWD+SC+sag(2) 1,574.42 47.56 317.87 1,404.15 1,259.65 425.48 -384.46 2,233,908.51 209,470.05 2.93 573.41 MWD+SC+sag(2) 1,636.86 47.07 316.40 1,446.48 1,301.98 459.12 -415.68 2,233,942.89 209,439.65 1.90 619.30 MWD+SC+sag(2) 1,698.99 46.81 315.83 1,488.90 1,344.40 491.84 -447.14 2,233,976.35 209,408.98 0.79 664.69 MWD+SC+sag(2) 1,761.06 47.40 315.96 1,531.15 1,386.65 524.49 -478.79 2,234,009.76 209,378.13 0.96 710.15 MWD+SC+sag(2) 1,824.06 45.95 315.12 1,574.38 1,429.88 557.21 -510.89 2,234,043.23 209,346.83 2.50 755.96 MWD+SC+sag(2) 1,886.84 45.01 314.84 1,618.40 1,473.90 588.85 -542.55 2,234,075.63 209,315.94 1.53 800.69 MWD+SC+sag(2) 1,948.76 45.02 314.43 1,662.17 1,517.67 619.62 -573.71 2,234,107.14 209,285.52 0.47 844.44 MWD+SC+sag(2) 2,010.25 45.10 314.32 1,705.60 1,561.10 650.06 -604.83 2,234,138.32 209,255.15 0.18 887.91 MWD+SC+sag(2) 2,072.96 45.58 313.41 1,749.68 1,605.18 680.96 -636.99 2,234,169.99 209,223.75 1.28 932.44 MWD+SC+sag(2) 2,134.62 45.85 313.45 1,792.73 1,648.23 711.31 -669.04 2,234,201.10 209,192.43 0.44 976.48 MWD+SC+sag(2) 2,194.77 46.17 312.95 1,834.51 1,690.01 740.93 -700.59 2,234,231.47 209,161.60 0.80 1,019.65 MWD+SC+sag(2) 2,257.93 46.99 312.63 1,877.92 1,733.42 772.10 -734.25 2,234,263.43 209,128.70 1.35 1,065.39 MWD+SC+sag(2) 2,318.65 45.95 314.83 1,919.75 1,775.25 802.52 -766.07 2,234,294.61 209,097.63 3.14 1,109.32 MWD+SC+sag(2) 2,382.07 44.82 316.50 1,964.29 1,819.79 834.80 -797.62 2,234,327.65 209,066.86 2.59 1,154.45 MWD+SC+sag(2) 2,440.99 45.25 316.33 2,005.93 1,861.43 865.00 -826.36 2,234,358.52 209,038.86 0.76 1,196.13 MWD+SC+sag(2) 2,506.95 45.78 315.94 2,052.15 1,907.65 898.92 -858.97 2,234,393.23 209,007.07 0.91 1,243.18 MWD+SC+sag(2) 2,570.19 45.80 317.31 2,096.24 1,951.74 931.87 -890.10 2,234,426.91 208,976.74 1.55 1,288.51 MWD+SC+sag(2) 2,633.27 46.37 316.66 2,139.99 1,995.49 965.10 -921.10 2,234,460.87 208,946.55 1.17 1,333.95 MWD+SC+sag(2) 2,695.49 46.71 318.79 2,182.79 2,038.29 998.51 -951.47 2,234,495.01 208,916.99 2.54 1,379.10 MWD+SC+sag(2) 2,758.03 46.82 320.20 2,225.64 2,081.14 1,033.15 -981.06 2,234,530.35 208,888.24 1.65 1,424.63 MWD+SC+sag(2) 2,821.15 47.48 319.85 2,268.56 2,124.06 1,068.62 -1,010.80 2,234,566.52 208,859.37 1.12 1,470.85 MWD+SC+sag(2) 2,882.48 46.29 320.27 2,310.48 2,165.98 1,102.94 -1,039.54 2,234,601.53 208,831.46 2.00 1,515.56 MWD+SC+sag(2) 2,944.11 46.88 320.45 2,352.84 2,208.34 1,137.41 -1,068.10 2,234,636.68 208,803.74 0.98 1,560.26 MWD+SC+sag(2) 3,006.90 47.45 319.64 2,395.53 2,251.03 1,172.71 -1,097.67 2,234,672.67 208,775.03 1.31 1,606.25 MWD+SC+sag(2) 3,067.28 45.89 319.73 2,436.96 2,292.46 1,206.20 -1,126.08 2,234,706.83 208,747.43 2.59 1,650.13 MWD+SC+sag(2) 3,129.10 46.22 318.54 2,479.86 2,335.36 1,239.86 -1,155.21 2,234,741.18 208,719.12 1.49 1,694.61 MWD+SC+sag(2) 3,190.56 46.57 318.49 2,522.25 2,377.75 1,273.19 -1,184.69 2,234,775.22 208,690.46 0.57 1,739.10 MWD+SC+sag(2) 3,253.94 47.27 317.90 2,565.54 2,421.04 1,307.70 -1,215.54 2,234,810.46 208,660.44 1.30 1,785.39 MWD+SC+sag(2) 3,316.38 47.03 317.52 2,608.00 2,463.50 1,341.56 -1,246.35 2,234,845.06 208,630.46 0.59 1,831.16 MWD+SC+sag(2) 1/3/2017 4:04:43PM Page 3 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Kalotsa 1 Project: Ninilchik Unit TVD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 1 wp04 @ 144.50usft Well: Kalotsa 1 North Reference: True Wellbore: Kalotsa 1 Survey Calculation Method: Minimum Curvature Design: Kalotsa 1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,378.48 45.09 317.52 2,651.09 2,506.59 1,374.54 -1,276.54 2,234,878.75 208,601.06 3.12 1,875.88 MWD+SC+sag(2) 3,440.78 45.23 317.11 2,695.02 2,550.52 1,407.01 -1,306.49 2,234,911.93 208,571.90 0.52 1,920.05 MWD+SC+sag(2) 3,504.12 45.97 317.07 2,739.34 2,594.84 1,440.16 -1,337.31 2,234,945.81 208,541.90 1.17 1,965.31 MWD+SC+sag(2) 3,566.32 46.32 316.25 2,782.43 2,637.93 1,472.78 -1,368.09 2,234,979.16 208,511.91 1.10 2,010.16 MWD+SC+sag(2) 3,627.95 47.06 316.06 2,824.71 2,680.21 1,505.12 -1,399.15 2,235,012.24 208,481.63 1.22 2,054.99 MWD+SC+sag(2) 3,690.90 46.83 317.60 2,867.68 2,723.18 1,538.67 -1,430.62 2,235,046.53 208,450.98 1.82 2,100.99 MWD+SC+sag(2) 3,752.70 45.62 317.05 2,910.44 2,765.94 1,571.47 -1,460.87 2,235,080.06 208,421.53 2.06 2,145.61 MWD+SC+sag(2) 3,815.33 45.43 318.05 2,954.32 2,809.82 1,604.45 -1,491.03 2,235,113.75 208,392.17 1.18 2,190.30 MWD+SC+sag(2) 3,877.76 44.26 316.76 2,998.58 2,854.08 1,636.86 -1,520.82 2,235,146.87 208,363.17 2.37 2,234.32 MWD+SC+sag(2) 3,938.72 42.21 315.98 3,042.99 2,898.49 1,667.08 -1,549.63 2,235,177.78 208,335.10 3.48 2,276.07 MWD+SC+sag(2) 4,000.74 40.99 316.27 3,089.37 2,944.87 1,696.77 -1,578.17 2,235,208.14 208,307.28 1.99 2,317.24 MWD+SC+sag(2) 4,061.95 40.09 317.40 3,135.88 2,991.38 1,725.78 -1,605.39 2,235,237.80 208,280.77 1.90 2,357.02 MWD+SC+sag(2) 4,123.68 38.99 317.21 3,183.49 3,038.99 1,754.66 -1,632.03 2,235,267.31 208,254.82 1.79 2,396.32 MWD+SC+sag(2) 4,186.92 38.76 318.20 3,232.72 3,088.22 1,784.02 -1,658.74 2,235,297.31 208,228.83 1.05 2,436.01 MWD+SC+sag(2) 4,249.34 36.58 318.64 3,282.13 3,137.63 1,812.55 -1,684.06 2,235,326.44 208,204.20 3.52 2,474.14 MWD+SC+sag(2) 4,311.12 34.55 318.40 3,332.38 3,187.88 1,839.47 -1,707.86 2,235,353.92 208,181.06 3.29 2,510.06 MWD+SC+sag(2) 4,373.95 33.68 317.59 3,384.40 3,239.90 1,865.66 -1,731.44 2,235,380.67 208,158.12 1.56 2,545.30 MWD+SC+sag(2) 4,435.69 32.09 317.82 3,436.24 3,291.74 1,890.45 -1,753.99 2,235,406.00 208,136.16 2.58 2,578.82 MWD+SC+sag(2) 4,497.84 31.17 316.72 3,489.16 3,344.66 1,914.40 -1,776.11 2,235,430.47 208,114.63 1.75 2,611.41 MWD+SC+sag(2) 4,560.54 31.50 317.19 3,542.72 3,398.22 1,938.23 -1,798.36 2,235,454.82 208,092.96 0.65 2,644.02 MWD+SC+sag(2) 4,624.06 30.41 317.31 3,597.19 3,452.69 1,962.22 -1,820.54 2,235,479.34 208,071.36 1.72 2,676.69 MWD+SC+sag(2) 4,685.71 29.91 318.88 3,650.49 3,505.99 1,985.26 -1,841.23 2,235,502.88 208,051.24 1.51 2,707.65 MWD+SC+sag(2) 4,745.90 28.29 319.46 3,703.08 3,558.58 2,007.41 -1,860.37 2,235,525.48 208,032.63 2.73 2,736.91 MWD+SC+sag(2) 4,809.53 27.10 317.89 3,759.42 3,614.92 2,029.62 -1,879.89 2,235,548.16 208,013.65 2.19 2,766.47 MWD+SC+sag(2) 4,872.41 25.13 317.56 3,815.88 3,671.38 2,050.10 -1,898.51 2,235,569.08 207,995.54 3.14 2,794.14 MWD+SC+sag(2) 4,934.90 23.21 318.41 3,872.89 3,728.39 2,069.11 -1,915.64 2,235,588.49 207,978.87 3.12 2,819.73 MWD+SC+sag(2) 4,996.97 21.01 317.54 3,930.39 3,785.89 2,086.47 -1,931.27 2,235,606.22 207,963.66 3.58 2,843.09 MWD+SC+sag(2) 5,059.09 19.48 316.81 3,988.67 3,844.17 2,102.23 -1,945.88 2,235,622.33 207,949.44 2.50 2,864.58 MWD+SC+sag(2) 5,120.84 19.58 315.88 4,046.87 3,902.37 2,117.17 -1,960.13 2,235,637.61 207,935.55 0.53 2,885.22 MWD+SC+sag(2) 5,184.46 17.90 316.73 4,107.12 3,962.62 2,131.94 -1,974.25 2,235,652.71 207,921.79 2.68 2,905.66 MWD+SC+sag(2) 5,246.13 16.52 316.75 4,166.02 4,021.52 2,145.23 -1,986.75 2,235,666.30 207,909.60 2.24 2,923.90 MWD+SC+sag(2) 5,307.58 14.89 319.06 4,225.18 4,080.68 2,157.56 -1,997.91 2,235,678.89 207,898.74 2.84 2,940.53 MWD+SC+sag(2) 5,369.98 13.42 316.37 4,285.68 4,141.18 2,168.86 -2,008.16 2,235,690.43 207,888.77 2.58 2,955.78 MWD+SC+sag(2) 5,430.89 13.49 315.35 4,344.92 4,200.42 2,179.03 -2,018.03 2,235,700.84 207,879.15 0.41 2,969.95 MWD+SC+sag(2) 5,493.64 12.29 316.34 4,406.09 4,261.59 2,189.06 -2,027.79 2,235,711.11 207,869.64 1.94 2,983.95 MWD+SC+sag(2) 5,556.54 11.35 319.99 4,467.66 4,323.16 2,198.65 -2,036.39 2,235,720.90 207,861.27 1.91 2,996.82 MWD+SC+sag(2) 5,618.10 9.80 316.71 4,528.17 4,383.67 2,207.10 -2,043.88 2,235,729.53 207,853.99 2.70 3,008.11 MWD+SC+sag(2) 5,680.12 8.66 316.35 4,589.38 4,44.4.88 2,214.32 -2,050.72 2,235,736.91 207,847.32 1.84 3,018.06 MWD+SC+sag(2) 5,742.04 7.11 315.62 4,650.72 4,506.22 2,220.44 -2,056.62 2,235,743.16 207,841.57 2.51 3,026.55 MWD+SC+sag(2) 5,804.08 6.15 319.76 4,712.34 4,567.84 2,225.72 -2,061.45 2,235,748.56 207,836.87 1.73 3,033.71 MWD+SC+sag(2) 1/3/2017 4:04:43PM Page 4 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Kalotsa 1 Project: Ninilchik Unit TVD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 1 wp04 @ 144.50usft Well: Kalotsa 1 North Reference: True Wellbore: Kalotsa 1 Survey Calculation Method: Minimum Curvature Design: Kalotsa 1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,867.09 5.45 322.03 4,775.03 4,630.53 2,230.65 -2,065.47 2,235,753.59 207,832.96 1.17 3,040.06 MWD+SC+sag(2) 5,928.35 4.50 312.89 4,836.06 4,691.56 2,234.58 -2,069.02 2,235,757.60 207,829.51 2.02 3,045.36 MWD+SC+sag(2) 5,991.60 2.82 304.46 4,899.18 4,754.68 2,237.15 -2,072.12 2,235,760.25 207,826.47 2.78 3,049.35 MWD+SC+sag(2) 6,053.84 1.42 273.43 4,961.38 4,816.88 2,238.06 -2,074.16 2,235,761.21 207,824.46 2.83 3,051.40 MWD+SC+sag(2) 6,116.38 1.01 172.83 5,023.91 4,879.41 2,237.56 -2,074.86 2,235,760.73 207,823.74 3.02 3,051.51 MWD+SC+sag(2) 6,178.14 1.30 169.35 5,085.65 4,941.15 2,236.33 -2,074.66 2,235,759.49 207,823.91 0.48 3,050.48 MWD+SC+sag(2) 6,241.37 1.22 181.08 5,148.87 5,004.37 2,234.96 -2,074.54 2,235,758.11 207,824.00 0.43 3,049.38 MWD+SC+sag(2) 6,304.76 1.36 168.02 5,212.24 5,067.74 2,233.55 -2,074.40 2,235,756.70 207,824.11 0.51 3,048.25 MWD+SC+sag(2) 6,368.08 1.40 169.88 5,275.54 5,131.04 2,232.05 -2,074.11 2,235,755.20 207,824.36 0.09 3,046.95 MWD+SC+sag(2) 6,425.88 1.49 184.39 5,333.33 5,188.83 2,230.60 -2,074.04 2,235,753.75 207,824.40 0.65 3,045.85 MWD+SC+sag(2) 6,490.13 1.52 195.61 5,397.55 5,253.05 2,228.95 -2,074.34 2,235,752.10 207,824.06 0.46 3,044.84 MWD+SC+sag(2) 6,551.63 1.85 189.54 5,459.03 5,314.53 2,227.19 -2,074.72 2,235,750.35 207,823.64 0.61 3,043.80 MWD+SC+sag(2) 6,614.65 0.81 170.71 5,522.03 5,377.53 2,225.74 -2,074.82 2,235,748.91 207,823.50 1.77 3,042.81 MWD+SC+sag(2) 6,675.95 0.55 181.37 5,583.33 5,438.83 2,225.02 -2,074.75 2,235,748.19 207,823.55 0.47 3,042.24 MWD+SC+sag(2) 6,738.79 0.68 173.67 5,646.16 5,501.66 2,224.35 -2,074.72 2,235,747.51 207,823.57 0.24 3,041.72 MWD+SC+sag(2) 6,800.86 0.70 182.38 5,708.23 5,563.73 2,223.60 -2,074.69 2,235,746.77 207,823.57 0.17 3,041.16 MWD+SC+sag(2) 6,862.81 0.79 163.35 5,770.17 5,625.67 2,222.82 -2,074.59 2,235,745.98 207,823.66 0.42 3,040.51 MWD+SC+sag(2) 6,925.24 0.74 175.70 5,832.60 5,688.10 2,222.00 -2,074.43 2,235,745.16 207,823.80 0.28 3,039.80 MWD+SC+sag(2) 6,986.89 1.05 173.54 5,894.24 5,749.74 2,221.04 -2,074.34 2,235,744.20 207,823.87 0.51 3,039.04 MWD+SC+sag(2) 7,047.67 1.29 182.32 5,955.01 5,810.51 2,219.81 -2,074.31 2,235,742.96 207,823.87 0.49 3,038.11 MWD+SC+sag(2) 7,110.02 0.67 1.94 6,017.35 5,872.85 2,219.47 -2,074.32 2,235,742.63 207,823.85 3.14 3,037.87 MWD+SC+sag(2) 7,172.75 1.06 359.91 6,080.08 5,935.58 2,220.42 -2,074.31 2,235,743.57 207,823.88 0.62 3,038.56 MWD+SC+sag(2) 7,235.04 0.66 1.89 6,142.36 5,997.86 2,221.35 -2,074.30 2,235,744.51 207,823.92 0.64 3,039.23 MWD+SC+sag(2) 7,298.93 0.60 358.44 6,206.24 6,061.74 2,222.05 -2,074.30 2,235,745.21 207,823.94 0.11 3,039.75 MWD+SC+sag(2) 7,361.78 0.82 348.17 6,269.09 6,124.59 2,222.82 -2,074.40 2,235,745.98 207,823.85 0.40 3,040.38 MWD+SC+sag(2) 7,424.60 0.64 345.08 6,331.90 6,187.40 2,223.60 -2,074.58 2,235,746.76 207,823.69 0.29 3,041.08 MWD+SC+sag(2) 7,487.36 0.74 0.97 6,394.66 6,250.16 2,224.35 -2,074.66 2,235,747.51 207,823.62 0.34 3,041.68 MWD+SC+sag(2) 7,551.58 0.76 359.84 6,458.87 6,314.37 2,225.19 -2,074.66 2,235,748.35 207,823.65 0.04 3,042.29 MWD+SC+sag(2) 7,614.89 0.59 1.74 6,522.18 6,377.68 2,225.93 -2,074.65 2,235,749.09 207,823.68 0.27 3,042.83 MWD+SC+sag(2) 7,677.11 0.75 2.67 6,584.40 6,439.90 2,226.66 -2,074.62 2,235,749.82 207,823.72 0.26 3,043.35 MWD+SC+sag(2) 7,739.17 0.92 338.60 6,646.45 6,501.95 2,227.53 -2,074.78 2,235,750.69 207,823.58 0.62 3,044.10 MWD+SC+sag(2) 7,800.72 0.84 324.43 6,707.99 6,563.49 2,228.36 -2,075.23 2,235,751.53 207,823.16 0.38 3,045.00 MWD+SC+sag(2) 7,862.51 0.77 339.91 6,769.78 6,625.28 2,229.11 -2,075.63 2,235,752.30 207,822.77 0.37 3,045.84 MWD+SC+sag(2) 7,924.27 1.20 328.68 6,831.53 6,687.03 2,230.06 -2,076.11 2,235,753.25 207,822.31 0.76 3,046.85 MWD+SC+sag(2) 7,986.32 1.13 329.83 6,893.56 6,749.06 2,231.14 -2,076.76 2,235,754.35 207,821.70 0.12 3,048.09 MWD+SC+sag(2) 8,048.84 1.51 324.85 6,956.07 6,811.57 2,232.35 -2,077.54 2,235,755.58 207,820.94 0.63 3,049.50 MWD+SC+sag(2) 8,110.92 1.34 316.59 7,018.13 6,873.63 2,233.54 -2,078.51 2,235,756.80 207,820.00 0.43 3,051.04 MWD+SC+sag(2) 8,172.75 1.27 315.98 7,079.94 6,935.44 2,234.56 -2,079.48 2,235,757.84 207,819.05 0.12 3,052.45 MWD+SC+sag(2) 8,234.04 1.12 333.35 7,141.22 6,996.72 2,235.59 -2,080.22 2,235,758.88 207,818.34 0.64 3,053.70 MWD+SC+sag(2) 8,295.57 1.19 323.00 7,202.74 7,058.24 2,236.63 -2,080.88 2,235,759.94 207,817.71 0.36 3,054.92 MWD+SC+sag(2) 1/3/2017 4:04:43PM Page 5 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Kalotsa 1 Project: Ninilchik Unit TVD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 1 wp04 @ 144.50usft Well: Kalotsa 1 North Reference: True Wellbore: Kalotsa 1 Survey Calculation Method: Minimum Curvature Design: Kalotsa 1 Database: Sperry EDM-NORTH US+CANADA 'Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,357.85 1.21 322.93 7,265.00 7,120.50 2,237.67 -2,081.66 2,235,761.00 207,816.95 0.03 3,056.21 MWD+SC+sag(2) 8,421.11 1.38 321.06 7,328.25 7,183.75 2,238.80 -2,082.54 2,235,762.15 207,816.09 0.28 3,057.64 MWD+SC+sag(2) 8,483.13 1.63 326.01 7,390.25 7,245.75 2,240.11 -2,083.51 2,235,763.48 207,815.16 0.45 3,059.26 MWD+SC+sag(2) 8,544.73 1.68 303.52 7,451.82 7,307.32 2,241.34 -2,084.75 2,235,764.74 207,813.95 1.05 3,061.00 MWD+SC+sag(2) 8,606.96 1.66 316.29 7,514.02 7,369.52 2,242.49 -2,086.13 2,235,765.92 207,812.59 0.60 3,062.79 MWD+SC+sag(2) 8,669.06 2.09 303.98 7,576.09 7,431.59 2,243.78 -2,087.69 2,235,767.25 207,811.06 0.94 3,064.79 MWD+SC+sag(2) 8,731.48 2.26 304.38 7,638.47 7,493.97 2,245.11 -2,089.65 2,235,768.62 207,809.14 0.27 3,067.10 MWD+SC+sag(2) 8,791.48 2.29 303.02 7,698.42 7,553.92 2,246.43 -2,091.63 2,235,769.99 207,807.19 0.10 3,069.41 MWD+SC+sag(2) 8,824.04 1.69 296.05 7,730.96 7,586.46 2,246.99 -2,092.61 2,235,770.58 207,806.23 1.98 3,070.49 MWD+SC+sag(2) 8,866.00 . 1.69 296.05 7,772.90, 7,628.40 2,247.54 -2,093.72 2,235,771.15 207,805.13 0.00 3,071.64 PROJECTED to TD mitchalaird@halliburton.com °,,,°"'r,,,,,ipYO,,agram""'° Checked By: 2017.01.051513813-09'04y Approved By: Michael Calkins:per° °""° Date: 05 January 2017 1/3/2017 4:04:43PM Page 6 COMPASS 5000.1 Build 81 1 • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. NINU Kalotsa 1 Date Run 18-Dec-16 County Kenai State Alaska Supv. Pederson/ Wall CASING RECORD Surface '' TD 1,518.00 Shoe Depth: 1,509.00 PBTD: 1,424.00 No.Jts.Delivered 43 No.Jts.Run 36.5 No.Jts.Returned 7 Ftg.Delivered Ftg.Run 1,486.66 Ftg.Returned Length Measurements W/O Threads Ftg.Cut Jt. Ftg.Balance RKB 18.30 RKB to BHF RKB to CHF RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Shoe _ 1.65 1,509.33 1,507.68 2 Casing 7 5/8 29.70 L-80 BTC 82.39 1,507.68 1,425.29 Float Collar 1.27 1,425.29 1,424.02 35 Casing 7 5/8 29.70 L-80 BTC 1,397.48 1,424.02 26.54 Hanger and Pup 3.87 26.54 22.67 Csg Wt.On Hook: 45 Type Float Collar: Weatherford Type 402 No.Hrs to Run: 3.5 Csg Wt.On Slips: Type of Shoe: Weatherford Bullnose Type 30 Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg X Yes No 10 Ft.Min. 9.2 PPG Fluid Description: Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: Yes No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: Two on shoe joint,one on shoe track,every other joint to 300'Total 17 bow springs. CEMENTING REPORT Shoe @ 1509 FC @ 1,424.00 Top of Liner Preflush(Spacer) Type: MudPush II Density(ppg) 10 Volume pumped(BBLs) 23 Lead Slurry Type: Class A Sacks: 207 Yield: 2.44 Density(ppg) 12 Volume pumped(BBLs) 89.6 Mixing/Pumping Rate(bpm): 4.8 Tail Slurry w Type: Class A Sacks: 126 Yield: 1.22 Density(ppg) 15.4 Volume pumped(BBLs) 27.4 Mixing/Pumping Rate(bpm): 4.8 w Post Flush(Spacer) 1— cc Type: Density(ppg) Rate(bpm): Volume: it Displacement: Type: Spud Mud Density(ppg) 9.2 Rate(bpm): 4.8 Volume(actual/calculated): 67/65.4 FCP(psi): 550 Pump used for disp: SL Bump Plug? X Yes No Bump press 1025 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 20 Cement In Place At: 22:15 Date: 12/18/2016 Estimated TOC: 0 Method Used To Determine TOC: Returns Post Job Calculations: 1. Calculated Cmt Vol @ 0%excess: 79 Total Volume cmt Pumped: 117 Cmt returned to surface: 20 Calculated cement left in wellbore: 97 ...LF+ OH volume Calculated: 79 OH volume actual: 97 Actual%Washout: 38 www.wellez.net WellEz Information Management LLC ver_102716bf ti- -i- 1• K 7% .. _ Q 3 S, ,4, / S�O( . 5 g /24 i, • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. NINU Kalotsa 1 Date Run 31-Dec-16 County Kenai State Alaska Supv. Montague/Dorr CASING RECORD Production V TD 8,866.00 Shoe Depth: 8,846.00 PBTD: 8,600.00 No.Jts.Delivered No.Jts.Run 218 No.Jts.Returned Ftg.Delivered Ftg.Run 8,846.00 Ftg.Returned Length Measurements W/0 Threads Ftg.Cut Jt. Ftg.Balance RKB 18.30 RKB to BHF RKB to CHF RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Shoe 5 DWC Weatherford 1.63 8,846.00 8,844.71 1 Casing 41/2 12.6 L-80 DWC GP 38.27 8,844.71 8,806.44 Float Collar 5 DWC Weatherford 1.63 8,806.44 8,805.12 186 Casing 41/2 12.6 L-80 DWC GP 7,479.03 8,805.12 1,326.09 Pup Joint 4 1/2 12.6 L-80 DWC GP 4.73 1,326.09 1,321.36 XO 5 DWC 0.73 1,321.36 1,320.63 Swell Packer 6 DWC Baker 21.11 1,320.63 1,299.52 XO 5 0.68 1,299.52 1,298.84 Pup Joint 4 1/2 12.6 L-80 DWC GP 14.00 1,298.84 1,284.84 31 Casing 41/2 12.6 L-80 DWC GP 1,260.53 1,284.84 24.31 Hanger Pup Joint _ 4 1/2 12.6 L-80 DWC 2.60 24.31 21.71 Casing Hanger 1.35 21.71 20.36 Csg Wt.On Hook: 55,000 Type Float Collar: Weatherford,Model 402E No.Hrs to Run: 17 Csg Wt.On Slips: Type of Shoe: Weatherford Bull Nose Float Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg Yes X No Ft.Min. 9.5 PPG Fluid Description: 6%KCL/PHPA CEMENTING REPORT Shoe @ 8846 FC @ 8,805.00 Top of Liner #N/A Preflush(Spacer) Type: Mud Push Density(ppg) 10.9 Volume pumped(BBLS) 23.5 Lead Slurry Type: Lead Sacks: 752 Yield: 1.69 Density(ppg) 13.5 Volume pumped(BBLS) 226.5 Mixing/Pumping Rate(bpm): 5 Tail Slurry w Type: Production Blend Sacks: 162 Yield: 1.34 o Density(ppg) 15.3 Volume pumped(BBLS) 38.8 Mixing/Pumping Rate(bpm): 5.2 u) Post Flush(Spacer) t- co cc Type: Water Density(ppg) 8.34 Rate(bpm): 5.5 Volume: 10 LL Displacement: Type: KCL Brine Density(ppg) 8.7 Rate(bpm): 6 Volume(actual/calculated): 124/124 FCP(psi): 2243 Pump used for disp: SLB Bump Plug? Yes X No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 84 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 3 Cement In Place At: 14:41 Date: 1/1/2017 Estimated TOC: 0 Method Used To Determine TOC: Returns -SC/14.11C-62.- a - Tor ct oof Ab Post Job Calculations: Calculated Cmt Vol @ 0%excess: 198 Total Volume cmt Pumped: 265.3 Cmt returned to surface: 3 Calculated cement left in wellbore: 262.3 OH volume Calculated: 180 OH volume actual: 220 Actual%Washout: 22 www.wellez.net WellEz Information Management LLC ver_102716bf /t'(- (-1- - (A lzs Z5 p s� a-'- Z/2 3/17 • Kalotsa 1 Days vs Depth FINAL o i Kalotsa 1 Actual 500 -Kalotsa 1 Plan 1000 1500 2000 2500 3000 3500 4000 r agi 4500 v 3 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 0 5 10 15 20 25 Days • • Kalotsa 1 MW vs Depth 0 1000 Kalotsa 1 Plan Kalotsa 1 Actual 2000 3000 4000 5000 6000 s a a 7000 3 z 8000 9000 10000 11000 12000 13000 14000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, May 03,2017 8:57 AM To: Taylor Nasse(tnasse@hilcorp.com) Cc: Quick, Michael J (DOA) Subject: Kalotsa#1 CBL log (PTD 216-132) Taylor, Can you forward me electronic copy of CBL for Kalotsa#1? V4 In future would be best to send me copy as soon as you log wells...generally takes vendor several weeks to get here. Also,the drilling records indicate that cement was returned to surface on the 4 1.2"casing. I missed that until now. 4%"x 7 5/8" is supposed to be a monitorable annulus when using a cement packer and this will have to be addressed after I look at log. The 10-407 should also indicate that a CBL was run in box 22. Hilcorp is not always indicating these on new completion reports. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.aov). 1 • • 216132 Seth Nolan Hilcorp Alaska, LLC 2 7 9 9 1 GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 fidrurpAbuok®.1.14 RECEIVED Fax: 907 777-8510 �/ E-mail: snolan@hilcorp.com FEB 15 2017 DATE 01/16/2017AOGCC DATA LoGGE':' /\1/2011 M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Kalotsa 1 Prints and elog data Prints ROP-EWR-ALD-CTN-DGR 5"/2"MD EWR-ALD-CTN-DGR 5"/2"TVD CD: Final Well Data Log Viewers 1/6/2017 1:44 PM File folder CGM 1/6/2017 1:44 PM Fie folder Defirative Survey 1/6/2017 1:44 PM File folder 46, I_W 1/6/2017 1:44 PM File folder 40, LAS 1/6/2017 1:44 PM Fde folder PDF 1/6/20171:94 PM File folder TIFF 1/6/2017 1:44 PM Fie folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 y��Received6 Date: • • 2 1 7 0 6 1 3 2 Seth Nolan Hilcorp Alaska, LLC / 0 GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 {filrnrp alttMka t,�.c Fax: 907 777-8510 ?) E-mail: snolan@hilcorp.com FEB 15 2017 DATE 02/14/2017 AOGCC DATA LOGGED To: Alaska Oil & Gas Conservation Commission 2 n'1/201? Makana Bender M.K.BENDER Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Kalotsa 1 Mudlog Prints and Digital data Prints 5"Formation.Log MD/TVD 2"Gas Ratio Log MD/TVD 2"Formation Log MD/TVD 2"Drilling Dynamics Log MD/TVD 2"LWD Combo Log MD/TVD Final Well Report CD: Final Well Data Log t errs 2/4/2017 3:50 PM File folder Daily Report 2/14/2017 8:09 AM File folder DM1 Data 2/14/2017 8:09 AM File folder Final Well Report 2/14/2017 8:09 AM File folder LAS Data 2114/2017 8:09 AM File folder I., Log PDFs 2/4/2017 3:50 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: `/�' '✓ Date: i I yOF T„ ie\tel y7—�s� THE STATE Alaska Oil and Gas ti ,,-s�� o Conservation Commission - _= fAI�ASI<:A - 333 West Seventh Avenue " -1 I— / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *.? Main: 907.279.1433 ®F ALA �� Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 1 Permit to Drill Number: 216-132 Sundry Number: 317-069 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -1e- Cathy 7Foerster Chair DATED this 1!S day of February, 2017. RBDMS (JL- 'r" 16 2017 • • RECEIVED STATE OF ALASKA FEB 0 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION £ZI' es f APPLICATION FOR SUNDRY APPROVALS , G ( 7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 2, Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT milling,N2 jetting0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development ❑✓ 216-132 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20657-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O 701A ' • Will planned perforations require a spacing exception? Yes 111No 0 Kalotsa 1 9.Property Designation(Lease Number): 10.Field/Pool(s): C061505(SHL),ADL384372(TPH,BHL) ' Ninilchik 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): Junk(MD): 8,866' 7,773' 8,617' 7,524' 2,488 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,509' 7-5/8" 1,509' 1,360' 6,890psi 4,790psi Intermediate Production 8,846' 4-1/2" 8,846' 7,499' 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 1,300'MD/1,212'ND;N/A;N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 2 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: February 20,2017 CommencingOperations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑., ' WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnasseCathilcorp.com Printed Name Chad Helgeson Title Operations Manager 1 Signature ',1107 Phone 907-777-8405 Date (417 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31-7- oCi2 �( Plug Integrity ❑ BOP Test � Mechanical Integrity Test ❑ Location Clearance El 44S 103 ir; Other: itt41 5.00 /as�.. ) 77& (c-T l/ Post Initial Injection MIT Req'd? Yes ❑ No ii ) JJ `�l / Spacing Exception Required? Yes 0-410 No Subsequent Form Required: /QW0 7 tike APPROVED BY RBDMS L`' PT 1 61,}0+17 Approved by: COMMISSIONER THE COMMISSION Date: 2—15 / Z1_2015 OpRell pi> Submit Form and Form 10-40 Revised11/2015 I a i I r 12 months from the date of approval. Attachments ig Duplicate 2� �" "0 z: Ir.(i • • Well Prognosis Well: Kalotsa#1 Ililcarp Alaska,LL Date:2/6/2017 Well Name: Kalotsa#1 API Number: 50-133-20657-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: Feb. 20th, 2017 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-189 First Call Engineer: Taylor Nasse (907)777-8354(0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(C) AFE Number: 1612639C Maximum Expected BHP: —3,241 psi @ 7,538' ND • (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: —2,488 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary Kalotsa #1 is a grass roots development well targeting gas sands in the Tyonek formation. This new well reached TD on 12/30/16. • The purpose of this work/sundry is to evaluate cement, cleanout cement to below proposed perf depths, jet the well dry with CT, and perforate. Notes Regarding Wellbore Condition • Well will be filled with filtered 6%KCI. • Slickline tag and make gauge ring run prior to starting work. J • An MIT-IA(7-5/8"x 4-1/2")will be performed to 2,500 psig for 30 minutes using the coiled tubing pumps prior to beginning of sundry work. _ L--3 C. 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(pre-Sundry work) 1. MIRU e-line and PT lubricator to 3,500 psi Hi 250 Low. 2. RIH w/CBL and PNL tool and log from PBTD to 200'. POOH. Coiled Tubing Procedure(start of Sundry work) 1 (07., >< 3. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. r-- 4. MU mill and motor BHA. 5. RIH and mill cement at 8,617'. Continue milling/cleanout to 8,660'."r 6. RU N2 pumping unit. 7. Drop ball and come online with N2 and jet well dry.' a. Estimated volume of displaced 6% KCI is 134 bbl. 1110 Well Prognosis Well: Kalotsa#1 Hilcorp Alaska,LL) Date:2/6/2017 8. Once well is dry,verify desired surface pressure to leave on well with Operations Engineer. 9. POOH w/coil. LD BHA. 10. RD Coiled Tubing. E-Line Procedure 11. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. Note that the well is pressurized with nitrogen. a. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 12. Perforate the Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns—see attached "Proposed Schematic"for proposed perforation intervals.All intervals are planned for 12 SPF so each may be shot twice.Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. 13. POOH. 14. If any of the sands are not commercial or wet,the zone will be permanently plugged back. 15. RD e-line. 16. Turn well over to production. Attachments: 1. Actual and Proposed Schematic 2. Coil BOPE Schematic 3. CT Flow Diagrams(Forward and Reverse Jetting) 4. Wellhead Diagram 0 0 Ninilchik SCHEMATIC Well Kalotsa #1 PTD: 216-132 API: 50-133-20657-00 Hikorp Alaska,LLC RKB=20.4' CASING DETAIL 16" "< Size Type Wt Grade Conn. ID Top Btm Conductor— 16" Driven to 84 X-56 Weld 15.01" Surf 120' . Set Depth 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,509' DWC/C 4-1/2" Prod Csg 12.6 L-80HT 1 3.958" Surf 8,846' *0 HT -°=+ `-�S- 1 a „it, Z.SZ2C P 5 7-5/8" ttn :. ;. 1 ' � JEWELRY DETAIL No. Depth ID OD Item 1 1,300' 3.958" 6.875" Baker Swell Packer 4'ip 04. xy g iyyY kti . .4 �. ,,„ n Y, 1 Y `'i 1.,..-1,.x.. *41 766.°, 4-1/2" w-. ,T i Gpt. ' a 1 44 PBTD=8,617'/PBTVD=7,524' TD=8,866'/TVD=7,773' Updated by TWN 1/31/2017 • S Ninilchik PROPOSED Well Kalotsa #1 inPTD: 216-132 Hileorp Alaska,LLC SCHEMATIC API: 50-133-20657-00 RKB=20.4' CASING DETAIL ht Os, Size Type Wt Grade Conn. ID Top Btm 16" Conductor- 16" Driven to 84 X-56 Weld 15.01" Surf 120' 3. Set Depth 7-5/8 Surf Csg 29.7 L-80 BTC 6.875 Surf 1,509' DWC/C l 4-1/2" Prod Csg 12.6 L-80HT 3.958" Surf 8,846' '70 JEWELRY DETAIL 7-5/8" dr IIII 01 No. Depth ID OD Item _, 1 1,300' 3.958" 6.875" Baker Swell Packer ' = TX •4 PERFORATION DETAIL r T1 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Ft Size Date T3 TX 4,667' . 4,731' 3,634' 3,690' 64 2-7/8" Proposed J T3A Ti 4,746' • 4,813' 3,703' 3,763' 67 2-7/8" Proposed i =' T5 T3 4,871' ' 4,893' 3,815' 3,835' 22 2-7/8" Proposed � --- T3 4, 908' • 4,918' 3,848' 3,857' 10 2-7/8" Proposed T5A 7 _ T3A 4,931' ` 4,958' 3,869' 3,894' 27 2-7/8" Proposed I -• -r. , T5C T5 5,020' ' 5,027' 3,952' 3,959' 7 2-7/8" Proposed I T6 T5A 5,058'. 5,083' 3,988' 4,011' 25 2-7/8" Proposed I. .�__ T5C 5,103' 5,119' 4,030' 4,045' 16 2-7/8" Proposed I - '.a�= T6B T6 5,150' ' 5,175' 4,074' 4,098' 25 2-7/8" Proposed .--- T7 T6B 5,275' ' 5,298' 4,194' 4,216' 23 2-7/8" Proposed 1 T8 T7 5,333' - 5,353' 4,250' 4,269' 20 2-7/8" Proposed T8 5,368' • 5,402' 4,284' 4,317' 34 2-7/8" Proposed - '.., !Ar T9A T9A 5,465' 5,478' 4,378' 4,391' 13 2-7/8" Proposed • T10A T9A 5,506' , 5,520' 4,418' 4,432' 14 2-7/8" Proposed v:14 V ` T14 T10A 5,547'• 5,555' 4,458' 4,466' 8 2-7/8" Proposed T10A 5,590'. 5,608' 4,501' 4,518' 18 2-7/8" Proposed .' =!r - T17 ` a.- T14 6,067 • 6,082' 4,975' 4,990' 15 2-7/8" Proposed -j __ T18 T17 6,295' • 6,340' 5,202' 5,247' 45 2-7/8" Proposed E T42 T18 6,417' . 6,437' 5,324' 5,344' 20 2-7/8" Proposed T18 6,445' 6,465' 5,352' 5,372' 20 2-7/8" Proposed ' T80 T18 6,472' 6,484' 5,379' 5,391' 12 2-7/8" Proposed .1'*t -* T83 T42 6,861' 6,870' 5,768' 5,777' 9 2-7/8" Proposed cz c [a. T80 7,824' 7,833' 6,731' 6,740' 9 2-7/8" Proposed ° T90 I . T83 7,863' • 7,896' 6,770' 6,803' 33 2-7/8" Proposed . * " T120 T90 8,013' 8,110' 6,920' 7,017' 97 2-7/8" Proposed T140 T90 8,149', 8,169' 7,056' 7,076' 20 2-7/8" Proposed 4-1/2" • T120 8,477' 8,489' 7,384' 7,396' 12 2-7/8" Proposed "' `` '".•' T140 8,566' 8,596' 7,473' 7,503' 30 2-7/8" Proposed PBTD=8,660'/PBTVD=7,567' T140 8,616' • 8,631' 7,523' 7,538' 15 2-7/8" Proposed TD=8,866'/TVD=7,773' Updated by TWN 1/31/2017 • • . n Ninilchik Gas Field Kalotsa #1 ei 411044*,ELI: Coil Tubing BOP ri Lubricator to injection head e 0 1 pl l 1.75" Tandem Stripper ®: Blind/Shear 4 1/16 10 Blind/Shear : -_-_ C -- I- €= Blind/Shear Blind/Shear :4 _ y - C.C OO - I _ _ • -_ I c- - Slip Slip _ :4 /- C: Pipe Pipe Mud Cross y --_ C _-_- 4 1/16 10M X 4 1/16 10M Outlet w/2- 2 1/16 10M full opening FMC valves - urum ' -11IllI ,It * 011 0 Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M Crossover spool 4 1/16 10M X 4 1/16 5M • • s ; g3 a 411 D U C < @ 1 I C 1- m U U to ' . Z Q O]O 11 1] Z !f 1 J O , 1 c U N b Z V, +, 3 3 11 Q. Ngg z 1EIS CT) II • >°Lil1100411 i iii N lI Z o L_ 0 o C V u O cl 0 • i ■ II 1 I' 1111 I� Iii IuII ® Ill! • i § gj I 41 1 CD U I- z" 1 .3 mo 1 .] H'` y 1 ] a) oz p 1 U Ld II1 Q NLc D w Owl t 6lllll I WI i (3' S C a vi ►•4 N z a) o a) Uo Z O a) LJ. O H i iib1in — 'mil h 0 10114ISI 4 N on lcivnu • wR -I a Y • C O H d v g • Q g • i V • A 41/101110 i Ij: iTh a R m it r O n a U N O Z g 0Ei 0 g 6 k 33 • 0 ' Ill Ninilchik Unit Kalotsa#1 and #2 01/13/2016 Ililrurp tla+►n.I.I.0 Ninilchik Unit Casing hanger,CW,11 x4 Sc Kalotsa#1 and 2 DWC/C box btm x 6.125"RH 16 x75/8x4h stub acme box top,w/75/8 od neck,4"type H BPV profile,DD-NL material BHTA,Otis,4 1/16 5M FE x 6.5 Otis quick union top 1 0 I 1111114111.111.11111 1r1 Isl 1*1tit Valve,Swab,WKM-Mb.. q 4 1/16 5M FE,HWO, . `EE trim ;,j v Valve,Wing,WKM-M, 111 olA 31/85M FE,HWO, Valve,Wing,SSV,WKM-M, IMI1 1 III EE trim 3 1/8 5M FE,w/15"Hydraulic operator 1 @X. Al: 1 0 I 1.. Ar WAI a ' il 7/ ,,r.) ii I Valve,Upper master, gr[. *, WKM-M, 4 1/16 5M FE,HWO,EE trim ir Uu Ira 1 0 1401 Nil l_I Valve,Master,WKM-M, i1# \C 41/165M FE,HWO, EE trim L :1 III 1117T771 lel D b. Tubing head,Cactus C-29L- _..=MR 16....umgollo I— HPS,13 5/8 SM x 11 5M,w/ — — u 2-2 1/16 5M SSO , w fd"•■ ■ ,)01 IML AM {_ 1 .lig ,.. Starting head,Cactus C-291, • .11.1111 =9111�1A — — .��I II�10s 135/85Mx16SOW,w/2-2 7.11, 1/165M SSO . . (6 1. =) IMI a::1.44." Ill-1• 16" 7 5/8" 4 h" • • STANDARD WELL PROCEDURE 11M►emp 1)aa6a,1.►.1: 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 FINAL v1 Page 1 of 1 091-(o-132. 111 • c Seth Nolan Hilcorp Alaska, LLC• ' E D E 1i V E D GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 FEB 15 2017 Tele: 907 777-8308 5(4/(C) Fax: 907 777-8510 ��,� E-mail: snolan@hilcorp.com DATE 01/16/2017 To: AOGCC Meredith Guhl 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL Kalotsa 1 WELL SAMPLE INTERVAL KALOTSA 1 120'-1260' KALOTSA 1 1260'-2580' KALOTSA 1 2580'-3840' KALOTSA 1 3840'-5100' KALOTSA 1 5100'-6600' KALOTSA 1 6600'-8000' KALOTSA 1 8000'-8866' Please include current contact information if different from above. Please acknowledge r= _'.t by signing and returning one copy of this transmittal or FAX to 907 777.8510 icecei ed I , Date: 2 / 5-// 7_ C • ■ 71 Conine e- Mu8 Docks ge" I — 5a� P 4(1 `* Yk5 fA4 we. So tr.;,r F COA v AG (FenV*10%5 .1 SA.xoin ((p9) Kpt off- 1 1) ;vek1ek o.)\ V OF rit, i y,\"�\I yyy,s� THE STATE Alaska Oil and Gas 4i1 -ice �, of Conservation Commission 71114r, __ ALAS ;A x___.�_ 333 West Seventh Avenue '�" '± " GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' Main: 907.279.1433 OFA.,Sgt Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 1 Hilcorp Alaska, LLC Permit to Drill Number: 216-132 Surface Location: 2200' FSL, 446' FWL, SEC. 7, T1S, R13W, SM, AK Bottomhole Location: 760' FNL, 1629' FEL, SEC. 12, T1S, R14W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 Hilcorp Alaska,LLC in the attached application, the following well logs are also required for this well: Kalsota 1 will be the first well drilling from a new drilling pad. The AOGCC requires samples, mud log, gamma ray, resistivity, and porosity logs from base o conductor pipe to total depth of the well. 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,suspension or abandonment of this 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, ia;41,4S& Cathy P. Foerster Chair DATED thisay of November, 2016. RECEIVEL STATE OF ALASKA A OIL AND GAS CONSERVATION COM411.1 NOV 17 2016 PERMIT TO DRILL Revised 20AAC25.005 .d"'4 rb '' la.Type of Work: 1 b. Proposed Well Class: Exploratory-Gas ❑ Service- WAG El Service-Disp ❑ 1 c.Specify if well is proposed for: Drill ❑., • Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj El Single Zone ❑✓ • Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas E• Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑� Single Well ❑ 11.Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 Kalotsa 1 • 3.Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 8,600' • TVD: 7,499' Ninilchik Field 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Beluga/Tyonek Gas Pool Surface: 2200'FSL,446'FWL,Sec 7,T1S,R13W,SM,AK (SHL)C061505(TPH,BHL)ADL384372 Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 1052'FNL, 1359'FEL,Sec 12,T1S, R14W,SM,AK N/A 11/21/2016 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 760'FNL, 1629'FEL,Sec 12,T1S,R14W,SM,AK C061505-1615 acres/ADL384372-3147 acres 6457'to the 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-209844 . y- 2233473 Zone-4 GL Elevation above MSL(ft): 126.5 • to Same Pool: 1,700'to Paxton 8 16.Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 46.3 degrees Downhole: 3401 • Surface: 2652- 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 84# J-55 Weld 80' Surface Surface 120' 120' Driven 9-7/8" 7-5/8" 29.7# L-80 BTC 1,500' Surface Surface 1,500' 1,349' 477 ft3 6-3/4" 4-1/2" 12.6# L-80 DWC/C HT 8,600' Surface Surface 8,600' 7,499' 1427 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 Size 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 0 Time v. Depth Plot 0 Shallow Hazard Analysis❑✓ Diverter Sketch ❑✓ Seabed Report El Drilling Fluid Program ❑✓ 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 Email mmyers hIIcorp.com Printed Name Monty Myers Title Drilling Engineer / Signature Phone 777-8431 Date I f./7 I Commission Use Only Permit to Drill / > API Number: Permit Approval See cover letter for other Number: 2l-' --i 50- /35-2°657-co-cc) Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: yOther: Ar- 3500 n„,_ 13 (0 ..fest— Samples req'd: Yes X No❑ Mud log req'd:Yes[ No❑ / /t HZS measures: Yes ❑ No[�,/. Directional svy req'd:Yes I 'No❑ x //t.i-r-- I A `" C3L hetet `a.Lr•e._ Spacing exception req'd: Yes CINoRs1 Inclination-only svy req'd:Yes❑ No Rr b j N re u�v_AP /6 5 Vic.47c4-- ..-- / Post initial injection MIT req'd:Yes❑ No❑ 5:3 Srfe4"'PN APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date:j/ �� ®1R r e l A21 A t a r y l(20 A Submit Form and Form 10-401(Revised 11/ 015) i months from the date of approval(20 AAC 25.005(g)) Attachments ip Duplicate Hilcorp Alaska, LLC P.O. Box 244027 111 • Monty Myers • Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Enema Company 11/17/2016 RECEIVED Commissioner Alaska Oil &Gas Conservation Commission NOV 17 2016 333 W. 7th Avenue Anchorage, Alaska 99501 AOGCC Re: Kalotsa 1 Revised Permit to Drill Dear Commissioner, Please see the attached Revised Permit to Drill for Kalotsa 1. We revised the surface hole location and cement volumes for the surface casing job. Drilling operations are expected to commence approximately November 21st 2016. 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 #1 Drilling Program Ninilchik Unit Rev 1 November 16th, 2016 i Kalotsa#1 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 16"Conductor Riser 11 11.0 Drill 9-7/8"Hole Section 14 12.0 Run 7-5/8" Surface Casing 18 13.0 Cement 7-5/8" Surface Casing 20 14.0 BOP N/U and Test 23 15.0 Drill 6-3/4"Hole Section 24 16.0 Run 4-1/2"Production Casing 29 17.0 Cement 4-1/2"Production Casing 32 18.0 RDMO 35 19.0 BOP Schematic 36 20.0 Wellhead Schematic 37 21.0 Days Vs Depth 38 22.0 Geo-Prog 39 23.0 Anticipated Drilling Hazards 40 24.0 Saxon Rig 169 Layout 42 25.0 FIT Procedure 43 26.0 Choke Manifold Schematic 44 27.0 Casing Design Information 45 28.0 6-3/4"Hole Section MASP 46 29.0 Spider Plot(NAD 27)(Governmental Sections) 47 30.0 Surface Plat(NAD 27) 48 31.0 Directional Plan(wp04a) 49 • • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 1.0 Well Summary Well Kalotsa#1 Pad&Old Well Designation Kalotsa#1 is a grass roots well on Kalotsa Pad • Planned Completion Type 4-1/2"Production tubing Target Reservoir(s) Beluga/Tyonek Planned Well TD, MD/TVD 8,600 MD/7,492' TVD PBTD, MD/TVD 8,500' MD/7,392' TVD Surface Location(Governmental) 2200' FSL, 446' FWL, Sec 7, T1S,R13W, SM,AK - Surface Location(NAD 27) X=209844.16, Y=2233473.89 • Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1052' FNL, 1359' FEL, Sec 12, T1S, R14W, SM,AK TPH Location(NAD 27) X=208089.41,Y=223459.69 TPH Location(NAD 83) BHL(Governmental) 760' FNL, 1629' FEL, Sec 12, T1S, R14W, SM,AK BHL(NAD 27) X=207826.00, Y=2235758.00 BHL(NAD 83) AFE Number 1612639D AFE Drilling Days 4 MOB, 18 DRLG AFE Completion Days AFE Drilling Amount $3,299,072 AFE Completion Amount $400,000 Maximum Anticipated Pressure (Surface) 2652 psi Maximum Anticipated Pressure (Downhole/Reservoir) 3401 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 Type 82 Single Ram Page 2 October, 2016 • S Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Energy Company Changes to Approved Permit to Drill Date: October 17,2016 Subject: Changes to Approved Permit to Drill for Kalotsa#1 File#: Kalotsa#1 Drilling Program Any modifications to Kalotsa#1 Drilling Program will be documented and approved below. Changes to an approved AP D will be communicated and approved by the AOGCC prior to continuing forward with • work. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Monty M Myers 10.17.2016 Drilling Engineer Date Page 3 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15.01" 14.822 17" 84 J-55 Weld 2980 1410 - 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 4790 683 6-3/4" 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 OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 October, 2016 • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 5.0 Internal Reporting Requirements 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@hilcorp.com, Ikeller@hilcorp.com , mmyers(a,hilcorp.com and cdinger@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!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 • Notify Drlg Manager 1. Paul Mazzolini: 0: 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 cdinger@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger(aihilcorp.com Page 5 October, 2016 • Kalotsa #1 11 Drilling Procedure Rev 1 Hilcorp Energy Company 6.0 Planned Wellbore Schematic Niniichik 111 PROPOSED Well Kalotsa#1 PTD: 000-000 API: 50-000-00000-00 Ir,. CASING DETAIL ' ..1 16" Mud Size Type Wt Grade Conn. ID Top Btm Weight Conductor 16" —Driven 84 X-56 Weld 15.01" Surf 120' N/A to Set Depth 7-5/8" Surf Csg 29.7 1-80 BTC 6.875" Surf 1,500' 8.8 ppg 4-1/2" Prod Csg 12.6 L-80 DHT/C 3.958" Surf 8,600' 9.5 ppg i. " •a Drilling Info Hole Section Casing MW Workstring 1 ' 9-7/8" 7-5/8" 8.8 ppg 4-1/2" f.- ' �� 6-3/4" 4-1/2" 9.2-10.5 ppg 4-1/2" i 7 1. 6.3;4• JEWELRY DETAIL Hole i'" No. Depth ID OD Item 1 1,300' 3.958" 6.875" Baker Swell Packer ' 'K Y, 41'2" r PBTD=8.500'I PBIVD=7.392' TD=9.600'/TVD=7.492' Page 6 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 7.0 Drilling / Completion Summary Kalotsa#1 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 268' MD. Maximum hole angle will be 46 • deg. and TD of the well will be 8600' TMD/7492' TVD, ending with 0 deg inclination left in the hole. Vertical section will be 3058 ft. Drilling operations are expected to commence approximately November 21st 2016. 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 / 1,349' 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 diverter and function test. 3. Drill 9-7/8" hole to 1500' MD. Run and cmt 7-5/8" surface casing. • 4. ND diverter,N/U &test 11" x 5M Townsend BOP. 5. Drill 6-3/4"hole section to 8,600' MD. Perform Wiper trip. • 6. POOH laying down drill pipe. 7. Run and cmt 4-1/2"production casing . 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: / r /vee J /t/( /1y 1. Surface hole: GR+Res LWD. • t*• 2. Production Hole: GR+Res+ Den/Neu LWD. • Vf.- '•€---04--4 ' I cet. /0 2S /4 3. Mud loggers from>rfaee irfg point to TD. • it, rte. 16, Page 7 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 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 #1. 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 10/10 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 both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: • None Page 8 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 9-7/8" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M 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 2-1/16"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:jim.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 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 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. L i etX loggers .required surface hole section. '� " (L 5 Vet_ , Z � 9.7 Mud to ' gg � q pen„ / , /g 4 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 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 10.0 N/U 21-1/4" Diverter 10.1 N/U 21-1/4" Diverter tr/ • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. Ensure to notify AOGCC inspector to witness function test of diverter. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Install wear bushing in well head Page 11 October,2016 • • Et Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 10.5 Rig and diverter orientation on Kalotsa pad: /' • +I /....... CI / / * / / / $ ,, // KAIOTS . , k. . /, \ •t' :',.. . 7 ` .:* ../ \\\\ , r Dive err ' \ # d/ / \ 4/ A, s 4 / - \ ,./$ , ; ////7// Page 12 October, 2016 • s II Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 10.6 Diverter Schematic • • €it Iii i4111111191111.13 i 111 111 111 ;11 III i Annular Preventerrt LISP I 21-W 2M Iii 'kill ill III 4/111600 Knife Gate III Iii III III l$1 :- 16"Diverter line Owerter Tee, 21-Y,"x 21-',/4" x • 2M wt 16'ANSI 150 outlet III iii fii if! III 16-% 3M x 21-Y."2M OSA 'a lima t ,1ttmmilIv I jr. 10-, , ,,, ! . r. ;,,,,, ■ilpN , ,,),,, Seaboard 16-W 3M i • I , Casing head Assy 1 _11)6' Page 13 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 11.0 Drill 9-7/8" Hole Section 11.1 P/U 9-7/8" directional drilling assy: • 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 TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 9-7/8"BHA (GR and Resare included in below BHA): ��re17?A- /�(s� ret CQi a ,r'�t u-4 !/zfie- L": it z,?_....y . 4r71 ce 't�-L'(,,Q, i 4,....k ib, ,14,., ,, ,16.-., ,i , 47 COMPONENT DATA Item Description Serial Number OD ID Gauge Weight Top Length Cumulative # (In) (In) (in) Ow Connection (h) Length (N) 1 9-718" PDC 6.020 2.250 9.875 83.45 P 4-1/2"REG 0.89 0.89 0 T SperryDritl Lobe 718-7.5 stg 7.000 4.952 ® " 30.00 30.89 Stabilizer -__ 9.625 _--- 3 6-3/4"Integral Blade 9 3/4" 6.760 2.500 9.750 105.59 B 4-1.2"IF 6.99 37.88 4 6-314"Float Sub 1111111111111 6.800 ® m 108.67 C 3.00 40.88 5 6 314'DM Collar(Directional) 6.720 3.125 103.40 B 4-112"IF 9.20 50.08 wii 6 3/4"DGR Collar(Gamma) ' 6.710 1.920 97.80 En= 6.50 IllEnl 7 6 3/4"EWR-P4 Collar(Resistivity) -- 6.710 2.000 104.30 B 4-112"IF 12.00 68.58 8 6 3/4"PWD Collar(Pressure) 111111111111 6.720 1.905 i 96.30 =CI IIIMMI 73.02 9 6 314"HCIM Collar(Processor) 6.750 1.920 101.70 B 4-12"IF 6.50 79.52 10 6 3/4"TM Collar(Telemetry) 11111111111 6.550 3.250 103.60 Ern 9.90 11 6.75"NM Flex Collar 6.450 2.875 89.23 B 4-112"IF 30.00 t 19.42 12 X Over Sub 4-112 IF x CDS 40 6.450 ® 13 4." DS 3.00IMMIl 13 3 its 4-1/2"HWDP 4.500 2.813 36.86 93.00 215.42 El X-Over Sub CDS 40 x 4-1/21F 6.300 2.625 87.79 B 4-112"IF 3.00 218.42 15 6-1/4"Weatherford Jar 6.270 2.250 91.68 B 4-1/2"IF 30.00 248.42 m X-Over Sub 4-1/2 IF x CDS 40 6.230 2.625 85.44 B 4.5"CDS40 3.00 251.42 EMI 5 its 4-1/2"HWDP 4.500 2.813 36.86 155.00 406.42 Total: 406.42 Page 14 October, 2016 •II • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 11.3 Primary Bit: 9-7/8" (251mm) MM65 PRODUCT SPECIFICATIONS Cutter Type SelectCutter SO, !ADC Code M323 4167 Body Type MATRIX t . Total gutter Cnttnl46 ' ) 4 ,`+ Cutlet Distribution II= • 4 Face ti iNt ,p^ Gauge 12 tt Is Up Drill 6 0 Number of Large Nozzles h Number of Medium Nozzles 0 tt, Number of Small Nozzles n Number of Micro Nozzles 0 , sr t Number of Ports(Size) 0 Number of Replaceable Ports(Sint) 0 - Junk Slot Areal tqin) 16.71 Nonnalued Face Volume 45.49". API Connection 4-1,2 REG.PIN Recommended Make-tip Torque* 12,461-17,766 Fritts. 1 Nominal Dimensions** it Make-Up Face to Nose 10.81 in-275 mn Gauge Length 2.5 in-64 mm Sleeve Length 0 in-0 mm Shank Diameter 6 in-152 mm Break Out Plate{Mat.Irlegsacyb t 1111954'440411 Approximate Shipping Weight 250Lbs.-113Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads.F16-16"Relieved Gage Material#771827 *Bit specific recnnmended makeup torque is a function oldie bit t.D.and actual bit sub O.D.oilfired as specified in A.PI RP7G Section A.S.?. **Design dimensions are nominal and may vary slightly on munufaclured product_tloltihurron trill hits and Services na.lels.are continuously reviewed and refined. Product specifications may chunk without notice. Z 2013 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terns and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.haliiburton-Cum Page 15 October,2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 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/ 1,349' 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 API FL pH 120-1500' 8.8—9.5 . 85-150 20-40 25-45 <10 8.5-9.0 Page 16 October, 2016 410 Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company System Formulation: Aquagel + FW spud mud Product Concentration 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. 11.10 No open hole logs are planned for the 9-7/8" hole section. Page 17 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 12.0 Run 7-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 7-5/8" casing running equipment. • 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" 7,630 ft-lbs Page 18 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY Outside Diameter 7.625 in Wall Thickness 0.375 in API Drift Diameter 6.750 in Nominal Weight 29.70 lbs/ft Nominal ID 6.875 in Alternative Drift Diameter n.a. Plain End Weight 29.06 lbs/ft Nominal cross section 8.541 in PERFORMANCE Steel Grade 180 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Tension Yield 683,000 in Internal Pressure Yield 6,890 psi Collapse Pressure 4,790 psi Available Seamless Yes Available Welded No CONNECTION DATA TYPE: BTC GEOMETRY Coupling Reg OD 8.500 in Threads per in 5 Thread turns make up 1 PERFORMANCE Steel Grade 180 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 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 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 13.0 Cement 7-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • 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 .16238 bpf= 19.5 110 16" Conductor x 7-5/8" casing annulus: 12.0 ppg LEAD: (1000' — 120') x .0382 bpf = 33 185 9-7/8" OH x 7-5/8" Casing annulus: Total LEAD: 53 bbl 295 ft3 ✓ 15.4 ppg TAIL: (1500'-1000')x .0382 bpf x 28.7 161.1 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: Total TAIL: 32.4 bbl 182 ft3 Page 20 October, 2016 • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy CeenPinY Cement Slurry Design: Lead Slurry (1000' MD to surface) Tail Slurry (1000' to 1500' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk 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 S002 CaCl2 0.35% BWOC D020 Extender 3.0% BWOC D177 CaCl2 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 21 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 13.13 Do not overdisplace by more than %z 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 a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • 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 success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to cdinger(a�hilcorp.com and mmyers@hikorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 October, 2016 • • 11 Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 14.0 BOP N/U and Test 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 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • 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 23 October,2016 • • II Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 15.0 Drill 6-3/4" Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray and Resistivity LWD functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.7 Workstring will be 4.5" 16.6# S-135 CDS40. Ensure to have enough 4-1/2" DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. Page 24 October, 2016 • • 111 Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 15.8 6-3/4" BHA: COMPONENT DATA Allillik hem 00 ID Gauge Weig Ix, Length Cumulative Description Serial Number (in} (ink ( , onnection (ft) Length (ft) inn HOBS EM65D PDC bit - 4.500 1.563 6.750 47 67 inal= 0.75 0.75 ® 5"SperryDrill Lobe 6/7-6.0 stg 5.000 3.120 Mil 48.00 111=11 24.00 MEM Slablrzer -- 6.560 _--- ® Float Sub 4.750 2.250 46 84 8 3-1/7"IF 2 25 21.00 O Welded Blade Stabilizer 4.840 2.000 6.500 52.00 8 3-1/2"IF 5 00 32.00 © 4 374'DM Collar 4.730 1.250 47 00 B 3-1/2"IF 920 41.20 4 314"Slim Phase 4 Collar ® 4.750 1.250 48.20 =BM 24.50 65.70 © Inline Stabilizer(ILS) 4.740 1.920 6.000 50.27 8 3-1.+2"IF 3.50 69.20 0 4 374"ALD Collar 4.750 1,250 5.625 45-50 8 3-112"IF 14,00 83.20 - S1aber -__ 5.625 ---- 9 4 314"CIN Collar 4.750 1.250 50 50 B 3-1/2"IF 11.00 94.20 10 43/4"PWD4.754 1.250 ® 47.90 B 3-1/2 IF 9.20 103.40 ® 4 314"TM HOC(Puller) 4.750 1.250 40.90 8 3-1/7'IF 11.00 114.40 ® 4 374"BAT Collar4.750 1.250 Eng 45.70 B NC 38 26.42 140.82 MEI 4 75"Flex Collar 4.750 2.250 ® 46 84 11133301 31.00 171 82 M 4.75"Flex Collar 4.750 2.250 46:84 8 3-1/2"IF 31.00 202.82 ® X-0 3-112"IF Pin X 4-112"CDS 40 Box 5.250 2.250 Mil 60.22 B 4.5'COS-40 MEM 205.57 nal 6 Joints 4-172'H!WDP ® 4.504 2.750 41.00 _ 185.00 390.57 ME X.0 4 112'COS-40 Pin X 3 1,2'IF box 5.300 2.250 ® 61 64 8 3.1/7'IF 2.75 393 32 E 4 3/4"Weatherford Hyd Jar IIIIIIIIIIIII 4,750 2.250 _ 46.84 11=111 30.00 MEM ® X-0 3-1/2"IF Pin X 4-1(2"CDS-40 Box 5.300 2.750 54.94 B 4.5'COS-40 2.75 426.07 20 13 Joints 4-1/2"HWDP 4.500 2.750 ME 41.00 400.00 826.07 Total: 826.07 BIT DATA Bit Number . Nozzles :6x10 Alt Size (In) : 6.750 TFA (In2) :0.4602 Manufacturer : HOBS Dull Grade On . Model : EM65D Dull Grade Out , Serial Number . Page 25 October, 2016 • • 111 Kalotsa#1 Drilling Procedure Rev 1 xiic Haw 15.9 Primary Bit: 6-3/4" (171mm) EM65D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling `" 4... IADC Code M323 Mk�` MATRIX o. 1 Body TypeI Ai 4 To4al(.utter Count 33 v Cutter Distribution J,jisln .tsapti r. 4 4 Fare 4 13 i Gauge I I 0 Up Drill 5 0 Number of Large Nozzles 0 Number of Medium Nozzles 0 a. Number of Small Nozzles 6 ' " Number of Micro Nozzles o t Illf ' Number of Pons(Size) 0 Number of Replaceable Ports(Size) 0 ern Junk Slot Area(sq in) 8.611 C) Normaluced Face Volume 34.6'$ API Connection 3-I.2 REG.PIN • , 5.4 Recommended Make-Up Torque* 5.173-7.665 Ft'lbrs. Nominal Dimensions" Make-Up Face to Nose 4.42 in-239 mm Gauge length 2 in-51 nun Sleeve Length 0 in-0 mm Shank Diameter 4S in•114 mm Break Out Plate(Mat,tl/Legacy93 1111953144030 Approximate Shipping Weight 90Lb s.-41 Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads.1116"Stepped Gage,Optimized Dual Row-"D"Feature Material 44761302 `Bit specific retutnmended make-up torque is a runrlicn of the bit I.D.and actual bit sub Q.D.atiliatd es vilified in AM RP?G Section A_5.2. **Design dimensions are nominal said may vary slightly on manufactured product.Halliburton Drill Bits and Senders models are continuously terose»cd and refined. Product specifitntiormf may change-iiinwut notice. lu 2013 Halliburton.All rights reserved_Sakes of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.com Page 26 October,2016 • • Kalotsa #1 111 Drilling Procedure Rev 1 Hilcorp Enemy Company 15.10 6-3/4"hole section mud program summary: 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: MD Mud Viscosity Plastic Yield Point pH HPHT Weight Viscosity 1,500'-8,600' 9.0—10.0 . 40-53 15-25 15-25 8.5-9.5 <11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCI 22 ppb (29 K 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 35, O_psi-X38-1 in. 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 27 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 1 Hi1COIp Energy Company 15.15 Conduct FIT to 13.5 ppg EMW. Note: Offset field test data predicts frac gradient at the 7-5/8"shoe to be between 11 - 13 ppg EMW. An 13.5 ppg FIT results in a 4 ppg kick margin while drilling with the planned MW of 9.5 ppg. 13 s � PPS Kick tolerance = (13.5-9.5)X(1349/7492) = 0.72 t 15.16 Drill 6-3/4" hole section to 8,600' MD/7,492' 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 other stand drilled. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and QFT 2 analysis for Lower Tyonek to total depth. 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 run and log well. 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 Install 4-1/2"pipe rams in BOP stack and RU and test. Page 28 October, 2016 • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 16.0 Run 4-1/2" Production Casing 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 M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5,800 ft-lbs 6,500 ft-lbs 7,200 ft-lbs Page 29 October, 2016 • Kalotsa#1 Drilling Procedure Rev 1 Hilcor Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Tubing 4-112 in 12.60 lb/ft(0.271 in) L-80 standard Material L-80 Grade WISINg 80.000 Minimum Yield Strength (psi) 1111111111111111111111111U BA 95,000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston,TX 77041 4.500 Nominal Pipe Body O.D. (in) Fax:n713-4 9-323404 3.958 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesr?vam-usa.00m 0.271 Nominal Wall Thickness (in) 12.60 Nominal Weight(lbs/ft) 12.25 Plain End Weight(lbs/ft) 3.600 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (lbs) 7,500 Minimum Collapse Pressure (psi) 8,430 Minimum Internal Yield Pressure(psi) 7,700 Hydrostatic Test Pressure (psi) 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 (%) Connection Performance Properties 288,000 Joint Strength (lbs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (lbs) 288,000 Compression Rating (lbs) 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-lbs) 6,500 Maximum Final Torque (ft-lbs) 7,200 Connection Yield Torque (ft-lbs) Page 30 October, 2016 S Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 16.6. Run in hole w/4-1/2" casing to the 7-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 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. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 31 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 17.0 Cement 4-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • 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 pump. • 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" Casing annulus: 500' x .02624 bpf= 13 bbls 73 ft3 6-3/4" OH X 4-1/2" Casing (8100' — 1500') X .025 X 1.35= 223 bbls 1252 ft3 Total LEAD: 236 bbls 1325 ft3 6-3/4" OH x 4-1/2" Casing annulus: (8,600'- 8,100') x .025 bpf x 1.35= 17 bbls 95 ft3 4-1/2" Shoe track: 80 x .019 bpf = 1.5 8.5 Total TAIL: 18.5 bbl 104 ft3 • i Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company Lead Slurry Tail Slurry • System Extended Lead System EasyBLOK System Density 13.5 lb/gal 15.3 lb/gal Yield 1.7 ft3/sk 1.33 ft3/sk Mixed 8.861 gal/sk 5.879 gal/sk Water 17.7. Drop wiper plug and displace with 3%KCl. 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 V2 shoe track. Shoe track volume is 1.5 bbls. 17.12. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours, test casing to 3500 psi and chart for 30 minutes. Page 33 October, 2016 I Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 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 success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to mmyers@hikorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 34 October, 2016 • S Kalotsa#1 1111 Drilling Procedure Rev 1 Hilcorp Energy Company 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 Page 35 October, 2016 • 0 Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 19.0 BOP Schematic • a, III li IT IZlill)IIIi► IE► III to 3.5" f / liitModee 6011i 11"-5000 _L___ 3.ri — .41:1110 ...,,_, , ,41ila. T-3 Energy I I ...1, H q� Model 7082 111 i - 11111 I 11"-5000 D u 1 fil III will III 1111 2.00' 1011: .74 .I I — I I 'I tela ihrictil 1f1 2 1/16 5M Kill Side 1/8 5M Choke Side ANIL:1 T 3 E 1 I1 -1 � 11 �II M ldel 7082 .Iiu — 'UI Ill 1!1 1S1 1u1 r-r.ni: 7.ng III Ill 1!I III III I )M111 . t riot — ii ,,,Le )81r c .„ -. .I +L ts I. tiILU" 518" Page 36 October, 2016 • ! II Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 20.0 Wellhead Schematic Nindchik Unit Casing hanger,CW,11 x 4% Kalotsa 41 and 2 DWC/C box btm x 6.125"RH 1605/8,4H stub acme box top,w/7S/8 od neck,4"type H BPV profile,DO NL material BHTA Otis,41/16 5M FE x 6.5 Otis pack union top at 11111181111111111111111111111 11111.11111 M M1 Ms Hs Valve,Swab,WKM-M ` A `V. dl/165M FE,HWO, 1C EE tnm 'am 7 Valve,Wing,WKM-M, ��y31/85M FE,HWO, t.at.1 MIDI EE trim lir I '4 1 ip, ,,,,:„.„,,,,,i... .; Valve,Upper master, WKM-M, 41/16 SM FE,HWO,EE trim Villi MI 11 i$18, Valve,Master,WKM-M, -7 HV VO,SM FE,HO, EE trim 4f Tubing head,Cactus C-294 PIM".— HPS,13 5/8 SM x 11 SM,w/ ••p.rrr 1, Fs�•8 I.- 2-2 1/16 5M SSO 111111 w . :,,...: . SII: .� AIM I: r.4 :I . mgismik"_ t_ Starting head,Cactus C-291, - —• ' — E - •am- 13 5/8 SM •r135/8SM x 16 SOW,w/2-2 — — 1/16 SM ISO ell MEI I� {M :} Page 37 October, 2016 • • Kalotsa #1 Drilling Procedure .��° . � .. Rev 1 Hilcorp Energy Company 21.0 Days Vs Depth Days Vs Depth 0 —Kalotsa#1 1000 KBU31-06X 2000 3000 4000 0. 5000 l0 Cd 6000 7000 8000 9000 10000 0 5 10 15 20 25 Days Page 38 October, 2016 • • II Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: Kalotsa 1 FIELD: Ninilchik(Pax-Dionne Area) SURFACE LOCATION X=209,850.08 BHL• X=207,826.00 AFE: (PROPOSED): Y=2,233,465.69 Y=2,235,758.00 PAD ID Kalotsa 1 COORD REF.SYSTEM NAD27 AK4 True North EST.KB: 144.5 PROPOSED TD: 8,600'MD , 7,492'TVD Rig RKB: 18 Saxon 169 -- API: TBD EST.GL: 126.5 Drill an 8600 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 FORMATION TOPS&GEOHAZARDS EXPECTED FLUID MD TVD(FT) SUBSEA DEPTH Est.Pressure EMW Beluga 120 gas 4352.57 3,356.50 -3212.00 1510.425 8.7 - Beluga 135 gas 4564.61 3,533.50 -3389.00 1590.075 8.7 Tyonek 7X gas 4661.90 3,617.50 -3473.00 1627.875 8.7 Tyonek T3 gas 4850.10 3,784.50 -3640.00 1703.025 8.7 Tyonek T6 gas 5144.88 4,056.50 -3912.00 1825.425 8.7 Tyonek 65 gas 7501.07 6,393.50 -6249.00 2877.075 8.7 Tyonek 83 gas 7800.07 6,692.50 -6548.00 3011.625 8.7 Tyonek 90 gas 7976.07 6,868.50 -6724.00 3090.825 8.7 Tyonek 110 gas 8274.07 7,166.50 -7022.00 3224.925 8.7 Tyonek 140 8545.07 7,437.50 -7293.00 3346.875 8.7 =Reservoir Objectives =Possible Geo Hazards r DATA COLLECTION REQUIREMENTS: Mud Logging: Surface Csg.To TD,samples collected at 20'intervals • LWD Data: LWD Triple Combo from surface casing to TD Other Log Data: COMPLETION TYPENOTES, h-n - •f - : Ani I.. -• R. - ,MIIII95% ARTIFICIAL LIFT EQUIPMENT OD F 16" I 136' PROSED PIPE SET DEPTHS 7" it 1500' 4-1/2" • �a�. TD�_.._� _.., ,. -. .. .e. ,.. . . a:.•= 1_ ill TUBING SIZEwm:i _,..iii OTHER COMMENTS NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HILCORP OR THEIR PARTNERS. Page 39 October, 2016 i Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 23.0 Anticipated Drilling Hazards 9-7/8" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are • available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 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 intial 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. J No abnormal pressures or temperatures are present in this hole section. Page 40 October, 2016 • S Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 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 btwn 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% KC1 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: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 41 October, 2016 • Kalotsa#1 II Drilling Procedure Rev 1 Hilcorp Energy Company 24.0 Saxon Rig 169 Layout _11F? .. .r+ -I gra FPE 7.,r ammo erolT= Mill � 1II ilkini,— . I IIIWir+.91 sham ` .e.Ex,E T+M1k I_1-=1_II-1 I-1-1 eros EgRiali ",,i— . \IYf�l 11 � � .NFIE rI� I �:o 1. :If E,L�I[1' I.. w ---_: _VIII . 1 vE r_..LC I , H. 111 I Fly —�[• d1� nllllllllllllllllll -UY • S dam• 31.['Tk.G*F _r. 1.. I� a. 3 . 11111111 IIIIIIIII I ' CH... cauauwncr�vuunrx; `Wc �-r5II Pm� a al IIiI n r ..0 ti En .LS9 1 I L vrmnV/wn n rnnxlrn ova n.. N.r Page 42 October, 2016 • II Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure.Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 43 October, 2016 • • II Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 26.0 Choke Manifold Schematic I A n f. J ' 4 ,4 rt u 1 i v e i lif "rte- ) ) i — '''•� v ':II .,`� �" ` ,firFE ir `j►`o w i I. ! - tti - _,_-• mot, Z r+• Q /! 9 i. S 1 �1� s. e :i�:+. , j:. r L „a..MI :N it t3 a c:4 _ ! , eih .1_0. 4,1 i. Mt te..47*". ...4 .._ y� u r C.2 py 1, ,� { f.� P _ :in NU 0 Llai 3in ...'4.`i. ; fIF1igiEiT 1 Iii II ri 4 a 1 '415 Ili ; ,7, i , , gll _.....124:- I 51. iAtA Ir ll e.' Page 44 October, 2016 • Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 27.0 Casing Design Information Calculation & Casing Design Factors Ninilchik DATE: 10/17/2016 WELL: Kalotsa #1 FIELD: Ninilchik DESIGN BY: Monty M Myers Design Criteria: Hole Size 9-7/8" Mud Density: 8.8 ppg Hole Size 6-3/4" Mud Density: 10 ppg Hole Size Mud Density: Drilling Mode MASP: 2652 psi (see attached MASP determination& calculation) MASP: Production Mode MASP: 3401 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.454 psi/ft)and the casing evacuated for the internal stress Casin• Section Calculation/Specification 1 2 3 4 Casing OD 7-5/8" 4-1/2" Top(MD) 0 0 Top(TVD) 0 0 Bottom (MD) 1,500 8,600 Bottom (TVD) 1,355 7,492 Length 1,500 8,600 Weight(PPO 29.7 12.6 Grade L-80 L-80 Connection BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 44,550 108,360 • • • Tension at Top of Section(lbs) 44,550 108,360 Min strength Tension(1000 lbs) 683 288 Worst Case Safety Factor(Tension) 15.33 2.66 Collapse Pressure at bottom (Psi) 589 3,259 Collapse Resistance w/o tension(Psi) 4,790 7,480 Worst Case Safety Factor(Collapse) 8.13 2.30 MASP (psi) 455 2,652 Minimum Yield (psi) 6,890 8,430 ( Worst case safety factor(Burst) 15.14 3.18 Page 45 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 28.0 6-3/4" Hole Section MASP ,14 Maximum Anticipated Surface Pressure Calculation 6-3/4"Hole Section Hilcorp Kalotsa#1 Ninilchik MD ND Planned Top: 0 0 Planned TD: 8600 7492 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Beluga 120 3356.5 3500.0 Gas Beluga 135 3533.5 1590.1 Gas 8.7 • 0.450 Tyonek TX 3617.5 1627.9 Gas 8.7 0.450 Tyonek T3 3784.5 1703.0 Gas 8.7 0.450 Tyonek T6 4056.5 1825.4 Gas 8.7 0.450 Tyonek 65 6393.5 2877.1 Gas 8.7 0.450 Tyonek 83 6692.5 3011.6 Gas 8.7 0.450 Tyonek 90 6868.5 3090.8 Gas 8.7 0.450 Tyonek 110 7166.5 3224.9 Gas 8.7 0.450 Tyonek 140 7437.5 3346.9 Gas 8.7 0.450 TD 7492 3400.0 Gas 8.7 0.454 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Susan Dionne 5 9.5-9.8 ppg • 1,299' 7,987' 2006 Susan Dionne 6 9.2-9.6 ppg 1,578' 4,520' 2008 Susan Dionne 7 9.2-10.1 ppg 1,450' 7,882' 2011 Assumptions: 1. Fracture gradient at shoe(1355'ND)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 1355 ft X 0.884 psi/ft 1198 psi 1198(psi)-[0.1(psi/ft)*1355(ft)]= 1062 psi MASP from pore pressure during production mode(Complete evacuation to gas) 7492 ft X 0.454 psi/ft 3401 psi Downhole 3401(psi)-[0.1(psi/ft)*7492(ft)]= 2652 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 to gas Page 46 October,2016 0 0 II Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) DIONNE 1 8HL• g p yrs _. 5924 ---p DIONNE 4 BML / °"'`°ter /// / KalutSt I RIII.1 .:,,,,,04" / / ` DIONNE 8 BHI.• // // DIONNE 6 BHL•''Y r ?PAXTON 9 8HL \ r � '�'hal,�t".1 1 PII 1 `b 00 IADL384372 0000 r 000 000 PAXTON4EHL• 00 / �` 00 / /// I PAXTON 8 8HLI 00 / 00 / / 0 / C061505 r 00 / I / 0 DIONNE 5 81-1L• I i /77gg 0� iNINILCHIK UNIT Q/Kalotsa I /111i . 5001S014W I 1 ��` // Kalotsa Pao , /// /., ,% ,/ // Legend / / ai I ,// / Kalotsa 1_SHL II I / / 11 / / Kalotsa 1_TPH t / rl • // /// + Kalotsa 1_BHL lit •PAXTON 2 8HL// ,/ Other Surface Well Locations / II i1 �1 // // NINILCHIK2 • Other Bottom Hole Locations I 1 I / I 1 I / Well Paths t 1 1 / DIONNE 7 BHA Ir I I I/ / Oil and Gas Unit Boundary Ili I j i / I' 111 I / !%. 'Ai• I // FINTON 5 8HL k / ADL384372 - C060385 C060385 Paxton Pad a Q)C060385 C060385 ADL392657 I II 0 1.000 2.000 Ninilchik Unit Feet Kalotsa 1n. Alaska State Plane Zone 4.NA027 Ilikorp Audio,1.1€ Map Date:10/17/2016 Page 47 October, 2016 / , F. ( p,� /_ l� i /1 � / GOVT LOT 2 -: 'AP /,, X FND 3 Y4" ALUM. MON,' _^�P 4725-S 1985 GOV'T LOT 3 F , JF i ,/0` i /p4 i /pe i / i /' I / KALOTSA PAD ! I / i .ALOT'"' -' Or'KALOTSA #1 i 446' FWL o AS-BUILT POSITION f r7 I LAT: 60' 06'14.8608"N I E LON: 151° 35' 24.5010"W v) v) N: 2233473.899'- ! LOT 1 F=- E: 209844.160' ! N ^0 446' FWL !i KN 85-129 GOVT LOT 1 z z 2200' FSL . I 0 o ASP ZONE 4 NAD 27 i P P ELEV: 126.5' (NGVD29) I v ( v)) Lu 2200' FSL (NTS) i I I i i i I N:2232605.58 i E:209377.32 i FND CAP ! USGLO 1919919 i le i SECTION 07 T1S R13W (NTS) ! SECTION 18 T1S R13W (NTS) t - NOTES 1.BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS AN OPUS i SOLUTION FROM NGS COORDINATES STATIONS"KENS CORS ARP","TSEA CORS ARP",AND"ZAN1 WAAS 1 CORS ARP"TO ESTABLISH THE POSITION OF"DIO 3"ON `NA\\X 1 SUSAN DIONNE PAD.THE GEODETIC POSITION OF DIO 3 WAS DETERMINED TO •� 'I 1 HAVE A LATITUDE OF 60°06'43.995"N AND A LONGITUDE OF 151°34'35.172'W.THE /\ .•c N.....O F AL q �� ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE ........ ,`P•.•' S �� N=2236337.935 =C • �) •7 9 �' E=1352842.572 NORTH j*., 4 9I /\ '• ELEV.139.79'(NGVD29) 00 /� / 2.BASIS OF VERTICAL CONTROL IS NGS BM V82 PID TT0586 LOCATED AT MILEPOST —( 04 :M.SCOTT McLANE 0 127.6 OF THE STERLING HIGHWAY HAVING AN ELEVATION OF 283.59 FEET NGVD29 ; ACCORDING TO NGS PUBLISHED DATA. SCALE I .• 4928-S ••'\ ~ 0 200 400 /�I<'')II/10114,•'',,c;' 3.COORDINATE CONVERSIONS(NAD83 TO NAD27)WERE DONE USING CORPSCON I I I I I SOFTWARE VERSION 6.0.1. FEET 1 h1\"`S:%%. \ / PROJECT HILCORP ALASKA, LLC REVISION: - /1 Consulting Inc KALOTSA#1 DATE: 11/09/16 NINILCHIK ALASKA DRAWN BY: BOB AS-BUILT SURFACE LOCATION SCALE: 1'=200' PROJECT NO. 167017 ENGINEERING/MAPPING/SURVEYING/TESTING NAD 27 BOOK NO. 16-04 P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION VOICE:(907)283.4218 FAX:(907)283-3265 // SEC. 07 TO1 S R13W SHEET w EMAIL:SAMCLANEQMCLANECG.COM Ilileorp 1klaskii. A i . I OF 1 SEWARD MERIDIAN, ALASKA • • 11 Kalotsa #1 Drilling Procedure Rev 1 Hilcorp Energy Company 30.0 Surface Plat (NAD 27) '5. 7" , Gi' .`�� I / GOVT LOT 2 P Cis N\ '' NO3X•u1.u.ROW. 4c'' /., 4)2•.,5 1945; GOVT LOT 3 i 4c 1 J /O� i Q i i • /tin / i / / KALOTSA PAD / 1 • OierssKALOTSA #1 i '--__ 446' F . 'D AS-BUILT POSITION I v n LAT: 60. 06'14.8608"N i a LOW: 151' 35' 24.5010'W a H N: 2233473.899' 1 t= E: 209844.160' • 1 OF 0 KN 446' FWL ' I ,.01 446' 85-129 GOVT LOT 1 2200' FSI. I 6 ASP ZONE 4 NAD 27 I v P ELEV: 126.5' (NGVD29) • i L rX 2200' FSL (NTS) 1 1 1 I 1 1 N:2232605,58 1 E:209377.32 i VS r BRASS CM VSOLO 1919 i ei SECTION 07 T1S R13W (NTS) i ii SECTION 18 TIS R13W (NTS) * -` NOTES ; I.BASIS OF GEODETIC CONTROL AND NAD03 POSITION(EPOCH 200.3)1S AN OPUS SOLUTION FROM NOS COORDINATES STATIONS'KENS CORS ARP'.'TSEA CORS ARP',AND 7AN1 WAAS 1 CORS ARP'TO ESTABUSH THE POSITION OF'010 3.ON `\\\\\\I SUSAN DIONIE PAD.THE GEODETIC POSITION OF DIO 3 WAS DETERMINED TO _ 1 HAVE A LATITUOE OF 130'0643.996•N AND A LONGITUDE OF 151'34'35.172'W.THE .r,E O.F!I G,y �/ ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE .4",.. . ,P S',f..// No2238337,935 .. col "9 �/ E•1352842.572 "•..... '• * / ELEV.139.79'INGVD29) �••••••••.. / ° /1T.L. /2/ee...v / 2.BASIS OF VERTICAL CONTROL IS NGS BM V82 PID TT0686 LOCATED AT MILEPOST —9� / i 127.6 OF THE STERLING HIGHWAY HAVING AN ELEVATION OF 283.59 FEET NGV029 I M SCOTT McLANE • ACCORDING TO NGS PUBLISHED DATA SCALE // ••• 4,72&s/ 3.COORDINATE CONVERSIONS(NAM TO NAM)WERE DONE USING CORPSCON o _.I i // '1!. Ifa'.. SOFTWARE VERSION 00 I. J I Ctrl I //II1j\\\\\%% HILCORP ALASKA,LLC " ^ Gs.aA1"f In,4 firKALOTSA#1 °A'r """'" NINILCHIK ALASKA OnAvler 1 AS-BUILT SURFACE LOCATION SCALE ,--943 PAOOKTNO 'ace' EH N0419Mn:u.Or1N5i$M ,449,TESTA, NAD 27 MCA AO 411 PO WA W SOLOOTM AK 9910 t%.i nin:i.. '.VICE 00,120-171, t10/1.2.113.3M1SEC.07 TO1S R13W 3NttI PAM.SU9CIA.E.8 A900000V I Iik.orp Alaska.1.1.1: SEWARD MERIDIAN,ALASKA 1 Page 48 October, 2016 • • II Kalotsa#1 Drilling Procedure Rev 1 Hilcorp Energy Company 31.0 Directional Plan (wp04a) Page 49 October, 2016 ! • Hilcorp Energy Company Ninilchik Unit Kalotsa Kalotsa 1 Kalotsa 1 Plan: Kalotsa 1 wp04a Standard Proposal Report 09 November, 2016 C HALLIBURTON Ammommomm Sperry Drilling Services • Project: N i n i lch i k Unit WELL DETAILS:Kalotsa NAD 1927(NADCON CONUS) Alaska Zone 04 HALLIBURTON Site: Kalotsa Ground Level: 126.50 - ----- --- Well: Kalotsa 1 +N/-S +EJ-W Northing Easting Latittude Longitude Sperry Grilling Wellbore: Kalotsa 1 0.00 0.00 2233473.90 209844.16 60.104128"N 151.590139°W Plan: Kalotsa 1 wp04a REFERENCE INFORMATION Co-ordinate(NIE)Reference:Well Kalotsa 1,True North Vertical(TVD)Reference:Kalotsa 1 wp04 410 144.50usft -1500— Measured Depth Reference:Calculation Method:Minimum Ctsa 1 u144.50usft Curvature -1000- -500— _ Start Dir 4°/100':250'MD,250'TVD 0- 500— 500 NOO 1000- - tx4;00 - 0 1500— 000 7 5/8"x 9 7/8" O ry00 Start Dir 2°/100':3786.01'MD,2928.8'TVD 2000— - 00 _ ,y0 2500— 000 c 3000— b00 _ Beluga 120 Lt) - c�0 3500---Beluga 135 _ a 0 - - Tyonek TX a _ 4000— Tyonek T3 - 5000 - Tyonek T6 5500 > 4500— a) 6000__ End Dir :6101.08'MD,5000'TVD 5000— 6500 5500— 7000 K-1 wp01 T65 Tgt2 6000— - Tyonek 65 - 7b00 K-1 wp01 T83 Tgt3 6500—- Tyonek 83 - - - K-1 wp01 T90 Tgt4 - 8000 7000— _ Tyonek 90 Total Depth:8600'MD,7498.92'TVD 4 1/2"x 6 3/4" 8600 T- yonek 110 _,- 7500— '`, Kalotsa 1 wp04a Tyonek 140 8000— 8500— 9000- 1 I I I I I I 1 1 1 1 1 1 1 I 1 1 1 1 1 I I I I I I I i i I I I I I I 1 1 1 1 1 1 1 I I f I I I I I 1 I 1 I I I I I 1 1 1 1 1 I I I I 1 1 1 1 1 I I I I 1 1 I I I I I I I I -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 Vertical Section at 317.21° (1250 usft/in) 1 lili•tx•l) • HAt_{.16URTON Project: Ninilchik Unit • WELL DETAILS: Kalotsa 1 — — Site: Kalotsa Ground Level: 126.50 Sperry Drilling Well: Kalotsa 1 +N/-S +E/-W Northing Easting Latittude Longitude Wellbore: Kalotsa 1 0.00 0.00 2233473.90 209844.16 60.104128°N 151.590139°w Plan: Kalotsa 1 wp04a REFERENCE INFORMATION Hu1eo C�'(� Co-ordinate(WE)Reference:Well Kalotsa 1,True North Vertical(TVD)Reference:Kalotsa 1 wp04 9 144.50usft Measured Depth Reference: Kalotsa 1 wp04(d1144.50usft Calculation Method:Minimum Curvature 3200— CASING DETAILS TVD TVDSS MD Size Name 3000— 1349.48 1204.98 1500.00 7-5/8 7 5/8"x 9 7/8" 7498.92 7354.42 8600.00 4-1/2 4 1/2"x 6 3/4" 2800- 2600— _Total Depth:8600'MD,7498.92'TVD 2400— Kalotsa I wp04a K-1 wp01 T90 Tgt4 '7499 -- K-1 wp01 T83 Tgt3 _ K-1 wp01 T65 T 81 2200— - End Dir:6101.08'MD,5000'TVD p 4 1/2"x 6 3/4" ,>^50 2000- - �ScP ryc0 1800— - 0 1600— + '� ^ 1400— . o 0° 1200- 0 1000- - 800- - 00- 150 600— End Dir:1407.54'MD,1285.6'TVD 00 400- 7 5/8"x 9 7/Ir- - '="\ 00- 75/8"x97/8"---'="\ - Start Dir 4°/100':250'MD,250'TVD 200— ,0°0 ��t0, 0— -200- 1I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 West(-)/East(+)(400 usft/in) • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company ND Reference: Kalotsa 1 wp04 @ 144.50usft ' Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft • Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04a Project Ninilchik Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kalotsa Site Position: Northing: 2,233,473.90 usft Latitude: 60.104128°N From: Map Easting: 209,844.16usft Longitude: 151.590139°W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.38 ° Well Kalotsa 1 Well Position +N/-S 0.00 usft Northing: 2,233,473.90 usft • Latitude: 60.104128°N +El-W 0.00 usft Easting: 209,844.16 usft • Longitude: 151.590139°W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 126.50 usft Wellbore Kalotsa 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 8/8/2016 15.94 73.13 55,161 Design Kalotsa 1 wp04a Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 18.00 0.00 0.00 317.21 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1100usft) (°/100usft) (°/100usft) (°) 18.00 0.00 0.00 18.00 -126.50 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 105.50 0.00 0.00 0.00 0.00 0.00 0.00 1,407.54 46.30 317.21 1,285.60 1,141.10 324.96 -300.79 4.00 4.00 0.00 317.21 3,786.01 46.30 317.21 2,928.80 2,784.30 1,586.92 -1,468.90 0.00 0.00 0.00 0.00 6,101.08 0.00 0.00 5,000.00 4,855.50 2,236.84 -2,070.49 2.00 -2.00 0.00 180.00 7,495.58 0.00 0.00 6,394.50 6,250.00 2,236.84 -2,070.49 0.00 0.00 0.00 0.00 8,600.00 0.00 0.00 7,498.92 7,354.42 2,236.84 -2,070.49 0.00 0.00 0.00 0.00 11/9/2016 4:33:25PM Page 2 COMPASS 5000.1 Build 81 • . Halliburton HALLIBURTDNJ Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company TVD Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -126.50 18.00 0.00 0.00 18.00 -126.50 0.00 0.00 2,233,473.90 209,844.16 0.00 0.00 100.00 0.00 0.00 100.00 -44.50 0.00 0.00 2,233,473.90 209,844.16 0.00 0.00 200.00 0.00 0.00 200.00 55.50 0.00 0.00 2,233,473.90 209,844.16 0.00 0.00 250.00 0.00 0.00 250.00 105.50 0.00 0.00 2,233,473.90 209,844.16 0.00 0.00 Start Dir 4°/100':250'MD,250TVD 300.00 2.00 317.21 299.99 155.49 0.64 -0.59 2,233,474.55 209,843.58 4.00 0.87 400.00 6.00 317.21 399.73 255.23 5.76 -5.33 2,233,479.78 209,838.97 4.00 7.85 500.00 10.00 317.21 498.73 354.23 15.97 -14.78 2,233,490.22 209,829.77 4.00 21.76 600,00 14.00 317.21 596.53 452.03 31.22 -28.90 2,233,505.81 209,816.02 4.00 42.55 700.00 18.00 317.21 692.63 548.13 51.45 -47.62 2,233,526.48 209,797.79 4.00 70.11 800.00 22.00 317.21 786.58 642.08 76.54 -70.85 2,233,552.12 209,775.17 4.00 104.30 900.00 26.00 317.21 877.92 733.42 106.39 -98.47 2,233,582.62 209,748.27 4.00 144.97 1,000.00 30.00 317.21 966.20 821.70 140.83 -130.36 2,233,617.83 209,717.23 4.00 191.90 1,100.00 34.00 317.21 1,050.98 906.48 179.71 -166.35 2,233,657.56 209,682.18 4.00 244.89 1,200.00 38.00 317.21 1,131.87 987.37 222.84 -206.27 2,233,701.64 209,643.31 4.00 303.65 1,300.00 42.00 317.21 1,208.46 1,063.96 270.00 -249.92 2,233,749.84 209,600.81 4.00 367.92 1,400.00 46.00 317.21 1,280.38 1,135.88 320.97 -297.10 2,233,801.93 209,554.87 4.00 437.37 1,407.54 46.30 317.21 1,285.60 1,141.10 324.96 -300.79 2,233,806.00 209,551.27 4.00 442.81 End Dir :1407.54'MD,1285.6'TVD 1,500.00 46.30 317.21 1,349.48 1,204.98 374.02 -346.20 2,233,856.14 209,507.06 0.00 509.65 7 518"x 9 7/8" 1,600.00 46.30 317.21 1,418.57 1,274.07 427.08 -395.32 2,233,910.36 209,459.24 0.00 581.95 1,700.00 46.30 317.21 1,487.65 1,343.15 480.13 -444.43 2,233,964.59 209,411.42 0.00 654.25 1,800.00 46.30 317.21 1,556.74 1,412.24 533.19 -493.54 2,234,018.81 209,363.60 0.00 726.55 1,900.00 46.30 317.21 1,625.82 1,481.32 586.25 -542.65 2,234,073.03 209,315.77 0.00 798.85 2,000.00 46.30 317.21 1,694.91 1,550.41 639.31 -591.76 2,234,127.26 209,267.95 0.00 871.15 2,100.00 46.30 317.21 1,764.00 1,619.50 692.37 -640.87 2,234,181.48 209,220.13 0.00 943.44 2,200.00 46.30 317.21 1,833.08 1,688.58 745.42 -689.99 2,234,235.70 209,172.31 0.00 1,015.74 2,300.00 46.30 317.21 1,902.17 1,757.67 798.48 -739.10 2,234,289.93 209,124.49 0.00 1,088.04 2,400.00 46.30 317.21 1,971.26 1,826.76 851.54 -788.21 2,234,344.15 209,076.67 0.00 1,160.34 2,500.00 46.30 317.21 2,040.34 1,895.84 904.60 -837.32 2,234,398.37 209,028.85 0.00 1,232.64 2,600.00 46.30 317.21 2,109.43 1,964.93 957.65 -886.43 2,234,452.60 208,981.03 0.00 1,304.94 2,700.00 46.30 317.21 2,178.52 2,034.02 1,010.71 -935.54 2,234,506.82 208,933.21 0.00 1,377.24 2,800.00 46.30 317.21 2,247.60 2,103.10 1,063.77 -984.65 2,234,561.05 208,885.39 0.00 1,449.53 2,900.00 46.30 317.21 2,316.69 2,172.19 1,116.83 -1,033.77 2,234,615.27 208,837.57 0.00 1,521.83 3,000.00 46.30 317.21 2,385.78 2,241.28 1,169.88 -1,082.88 2,234,669.49 208,789.75 0.00 1,594.13 , 3,100.00 46.30 317.21 2,454.86 2,310.36 1,222.94 -1,131.99 2,234,723.72 208,741.93 0.00 1,666.43 3,200.00 46.30 317.21 2,523.95 2,379.45 1,276.00 -1,181.10 2,234,777.94 208,694.11 0.00 1,738.73 3,300.00 46.30 317.21 2,593.04 2,448.54 1,329.06 -1,230.21 2,234,832.16 208,646.29 0.00 1,811.03 3,400.00 46.30 317.21 2,662.12 2,517.62 1,382.11 -1,279.32 2,234,886.39 208,598.46 0.00 1,883.32 3,500.00 46.30 317.21 2,731.21 2,586.71 1,435.17 -1,328.44 2,234,940.61 208,550.64 0.00 1,955.62 3,600.00 46.30 317.21 2,800.29 2,655.79 1,488.23 -1,377.55 2,234,994.83 208,502.82 0.00 2,027.92 3,700.00 46.30 317.21 2,869.38 2,724.88 1,541.29 -1,426.66 2,235,049.06 208,455.00 0.00 2,100.22 3,786.01 46.30 317.21 2,928.80 2,784.30 1,586.92 -1,468.90 2,235,095.70 208,413.87 0.00 2,162.40 Start Dir 2°/100':3786.01'MD,2928.8'TVD 11/9/2016 4:33:25PM Page 3 COMPASS 5000.1 Build 81 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company TVD Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (usft) (') (°) (usft) usft (usft) (usft) (usft) (usft) 2,793.99 3,800.00 46.02 317.21 2,938.49 2,793.99 1,594.33 -1,475.76 2,235,103.26 208,407.20 2.00 2,172.49 3,900.00 44.02 317.21 3,009.17 2,864.67 1,646.24 -1,523.80 2,235,156.31 208,360.41 2.00 2,243.23 4,000.00 42.02 317.21 3,082.28 2,937.78 1,696.30 -1,570.15 2,235,207.48 208,315.29 2.00 2,311.45 4,100.00 40.02 317.21 3,157.72 3,013.22 1,744.47 -1,614.73 2,235,256.71 208,271.88 2.00 2,377.08 4,200.00 38.02 317.21 3,235.41 3,090.91 1,790.67 -1,657.50 2,235,303.92 208,230.23 2.00 2,440.04 4,300.00 36.02 317.21 3,315.24 3,170.74 1,834.86 -1,698.40 2,235,349.08 208,190.41 2.00 2,500.25 4,350.69 35.01 317.21 3,356.50 3,212.00 1,856.46 -1,718.40 2,235,371.16 208,170.93 2.00 2,529.69 Beluga 120 4,400.00 34.02 317.21 3,397.13 3,252.63 1,876.97 -1,737.38 2,235,392.12 208,152.45 2.00 2,557.64 4,500.00 32.02 317.21 3,480.98 3,336.48 1,916.96 -1,774.39 2,235,432.99 208,116.41 2.00 2,612.13 4,561.54 30.79 317.21 3,533.50 3,389.00 1,940.49 -1,796.18 2,235,457.04 208,095.20 2.00 2,644.20 I Beluga 135 4,600.00 30.02 317.21 3,566.67 3,422.17 1,954.78 -1,809.40 2,235,471.64 208,082.32 2.00 2,663.66 4,658.37 28.85 317.21 3,617.50 3,473.00 1,975.83 -1,828.89 2,235,493.15 208,063.35 2.00 2,692.35 Tyonek TX 4,700.00 28.02 317.21 3,654.11 3,509.61 1,990.38 -1,842.35 2,235,508.02 208,050.24 2.00 2,712.17 4,800.00 26.02 317.21 3,743.19 3,598.69 2,023.72 -1,873.21 2,235,542.09 208,020.19 2.00 2,757.60 4,845.80 25.11 317.21 3,784.50 3,640.00 2,038.22 -1,886.64 2,235,556.92 208,007.11 2.00 2,777.37 Tyonek T3 4,900.00 24.02 317.21 3,833.80 3,689.30 2,054.76 -1,901.94 2,235,573.82 207,992.21 2.00 2,799.90 5,000.00 22.02 317.21 3,925.83 3,781.33 2,083.46 -1,928.51 2,235,603.14 207,966.35 2.00 2,839.00 5,100.00 20.02 317.21 4,019.17 3,874.67 2,109.78 -1,952.88 2,235,630.05 207,942.62 2.00 2,874.87 5,139.63 19.23 317.21 4,056.50 3,912.00 2,119.55 -1,961.92 2,235,640.03 207,933.81 2.00 2,888.19 Tyonek T6 5,200.00 18.02 317.21 4,113.70 3,969.20 2,133.70 -1,975.01 2,235,654.49 207,921.06 2.00 2,907.46 5,300.00 16.02 317.21 4,209.32 4,064.82 2,155.18 -1,994.90 2,235,676.44 207,901.70 2.00 2,936.74 5,400.00 14.02 317.21 4,305.90 4,161.40 2,174.20 -2,012.50 2,235,695.88 207,884.56 2.00 2,962.65 5,500.00 12.02 317.21 4,403.32 4,258.82 2,190.73 -2,027.81 2,235,712.78 207,869.66 2.00 2,985.18 5,600.00 10.02 317.21 4,501.47 4,356.97 2,204.76 -2,040.79 2,235,727.12 207,857.01 2.00 3,004.30 5,700.00 8.02 317.21 4,600.23 4,455.73 2,216.27 -2,051.45 2,235,738.88 207,846.64 2.00 3,019.98 5,800.00 6.02 317.21 4,699.47 4,554.97 2,225.24 -2,059.75 2,235,748.04 207,838.56 2.00 3,032.21 5,900.00 4.02 317.21 4,799.08 4,654.58 2,231.67 -2,065.69 2,235,754.61 207,832.77 2.00 3,040.96 6,000.00 2.02 317.21 4,898.94 4,754.44 2,235.53 -2,069.28 2,235,758.56 207,829.28 2.00 3,046.23 6,100.00 0.02 317.21 4,998.92 4,854.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 2.00 3,048.01 6,101.08 0.00 0.00 5,000.00 4,855.50 2,236.84 -2,070.49 2,235,759.90 207,828.10 2.00 3,048.01 End Dir :6101.08'MD,5000'TVD 6,200.00 0.00 0.00 5,098.92 4,954.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 6,300.00 0.00 0.00 5,198.92 5,054.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 6,400.00 0.00 0.00 5,298.92 5,154.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 6,500.00 0.00 0.00 5,398.92 5,254.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 6,600.00 0.00 0.00 5,498.92 5,354.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 6,700.00 0.00 0.00 5,598.92 5,454.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 6,800.00 0.00 0.00 5,698.92 5,554.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 6,900.00 0.00 0.00 5,798.92 5,654.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,000.00 0.00 0.00 5,898.92 5,754.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 11/9/2016 4:33:25PM Page 4 COMPASS 5000.1 Build 81 Halliburton HALLIBURTDN Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company TVD Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (") (") (usft) usft (usft) (usft) (usft) (usft) 5,854.42 7,100.00 0.00 0.00 5,998.92 5,854.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,200.00 0.00 0.00 6,098.92 5,954.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,300.00 0.00 0.00 6,198.92 6,054.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,400.00 0.00 0.00 6,298.92 6,154.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,494.58 0.00 0.00 6,393.50 6,249.00 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 Tyonek 65 7,495.58 0.00 0.00 6,394.50 6,250.00 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,500.00 0.00 0.00 6,398.92 6,254.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,600.00 0.00 0.00 6,498.92 6,354.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,700.00 0.00 0.00 6,598.92 6,454.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,793.58 0.00 0.00 6,692.50 6,548.00 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 Tyonek 83 7,800.00 0.00 0.00 6,698.92 6,554.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,900.00 0.00 0.00 6,798.92 6,654.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 7,969.58 0.00 0.00 6,868.50 6,724.00 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 Tyonek 90 8,000.00 0.00 0.00 6,898.92 6,754.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 8,100.00 0.00 0.00 6,998.92 6,854.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 8,200.00 0.00 0.00 7,098.92 6,954.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 8,267.58 0.00 0.00 7,166.50 7,022.00 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 Tyonek 110 I 8,300.00 0.00 0.00 7,198.92 7,054.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 8,400.00 0.00 0.00 7,298.92 7,154.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 8,500.00 0.00 0.00 7,398.92 7,254.42 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 ISI 8,538.58 0.00 0.00 7,437.50 7,293.00 2,236.84 -2,070.49 2,235,759.90 207,828.10 0.00 3,048.01 Tyonek 140 8,600.00 , 0.00 0.00 7,498.92 . 7,354.42 ' 2,236.84 -2,070.49 2,235,759.90 - 207,828.10 • 0.00 3,048.01 Total Depth:8600'MD,7498.92'TVD-4 1/2"x 6 3/4" II Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N1-S +EJ-W Northing Easting -Shape (") (") (usft) (usft) (usft) (usft) (usft) K-1 wp01 T65 Tgt2 0.00 0.00 6,394.50 2,236.84 -2,070.49 2,235,759.90 207,828.10 -plan hits target center -Circle(radius 50.00) K-1 wp01 T83 Tgt3 0.00 0.00 6,694.50 2,236.94 -2,070.49 2,235,760.00 207,828.10 -plan misses target center by 0.10usft at 7795.58usft MD(6694.50 TVD,2236.84 N,-2070.49 E) -Circle(radius 50.00) K-1 wp01 T90 Tgt4 0.00 0.00 6,869.50 2,236.84 -2,070.49 2,235,759.90 207,828.10 -plan hits target center -Circle(radius 50.00) 11/9/2016 4:33:25PM Page 5 COMPASS 5000.1 Build 81 1 • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company TVD Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04a Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 8,600.00 7,498.92 4 1/2"x 6 3/4" 4-1/2 6-3/4 1,500.00 1,349.48 7 5/8"x 9 7/8" 7-5/8 9-7/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (") (") 4,845.80 3,784.50 Tyonek T3 8,538.58 7,437.50 Tyonek 140 5,139.63 4,056.50 Tyonek T6 4,658.37 3,617.50 Tyonek TX 7,793.58 6,692.50 Tyonek 83 7,969.58 6,868.50 Tyonek 90 7,494.58 6,393.50 Tyonek 65 8,267.58 7,166.50 Tyonek 110 4,350.69 3,356.50 Beluga 120 4,561.54 3,533.50 Beluga 135 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 1,407.54 1,285.60 324.96 -300.79 End Dir :1407.54'MD,1285.6'TVD 3,786.01 2,928.80 1,586.92 -1,468.90 Start Dir 2°/100':3786.01'MD,2928.8'TVD 6,101.08 5,000.00 2,236.84 -2,070.49 End Dir :6101.08'MD,5000'TVD 8,600.00 7,498.92 2,236.84 -2,070.49 Total Depth:8600'MD,7498.92'TVD 11/9/2016 4:33:25PM Page 6 COMPASS 5000.1 Build 81 I • Hilcorp Energy Company Ninilchik Unit Kalotsa Kalotsa 1 Kalotsa 1 I Kalotsa 1 wp04a Sperry Drilling Services . Clearance Summary Anticollision Report 09 November,2016 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Kalotsa-Kalotsa 1-Kalotsa 1-Kalotsa 1 wp04a Well Coordinates: 2,233,473.90 N,209,844.16 E(60'06'14.86"N,151`35'24.50"W) 1 Datum Height: Kalotsa 1 wp04 @ 144.50usft Scan Range:0.00 to 8,600.00 usft.Measured Depth. Scan Radius is 1,058.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited t Geodetic Scale Factor Applied Version:5000.1 Build:81 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 2004.100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services I • Hilcorp Energy Company HALLI B U RTO N Ninilchik Unit Anticollision Report for Kalotsa 1 -Kalotsa 1 wp04a Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Kalotsa-Kalotsa 1-Kalotsa 1-Kalotsa 1 wp04a Scan Range: 0.00 to 8,600.00 usft.Measured Depth. Scan Radius is 1,058.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kalotsa Kalotsa 2-Kalotsa 2-Kalotsa 2 wp03 410.83 24.62 410.83 22.34 389.99 10.777 Centre Distance Pass- Kalotsa 2-Kalotsa 2-Kalotsa 2 wp03 425.00 24.68 425.00 22.32 404.06 10.470 Ellipse Separation Pass- Kalotsa 2-Kalotsa 2-Kalotsa 2 wp03 475.00 26.09 475.00 23.48 453.58 10.014 Clearance Factor Pass- Kalotsa 3-Kalotsa 3-Kalotsa 3 wp04 397.63 56.65 397.63 54.55 374.68 27.026 Centre Distance Pass- Kalotsa 3-Kalotsa 3-Kalotsa 3 wp04 425.00 56.77 425.00 54.53 401.35 25.413 Ellipse Separation Pass- Kalotsa 3-Kalotsa 3-Kalotsa 3 wp04 3,800.00 994.40 3,800.00 918.61 3,634.63 13.119 Clearance Factor Pass- Kalotsa 4-Kalotsa 4-Kalotsa 4 wp04 842.08 7.81 842.08 3.41 816.67 1.777 Ellipse Separation Pass- Kalotsa 4-Kalotsa 4-Kalotsa 4 wp04 850.00 8.16 850.00 3.56 824.18 1.775 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.00 1,500.00 Kalotsa 1 wp04a MWD+SC+sag 1,500.00 8,600.00 Kalotsa 1 wp04a MWD+SC+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 09 November,2016- 16:28 Page 2 of 4 COMPASS i • Hilcorp Energy Company HALLIBURTON Ninilchik Unit Anticollision Report for Kalotsa 1 -Kalotsa 1 wp04a Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Kalotsa 1 wp04 @ 144.50usft. Northing and Easting are relative to Kalotsa 1. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:-1.38°. Ladder Plot mi Mt •11N rp D i o Pi oM +- +- - -- -------- '� Al I i / i I I LEGEND • 6I I -- -- c I I i II 0) I t i 1 $ Kalotsa 21 Kalotsa 2,Kalotsa2wp03VO (n I rr t i I_____ ____� ___ Kalotsa 3:Kalotsa 3.KaoLra3wp04 V0 El2i i _ Kalotsa 4.Kalotsa4,Kalotsa4wp04V0 I I I I I I i I -9- Kalotsa 1 wp048 N 1 I/ L i I O 311 ?Fr I 1 02 I 0) I i I UI 1 I 0 0 700 1400 2100 2800 3500 Measured Depth(700 usft/in) 09 November.2016- 16:28 Page 3 of 4 COMPASS i ! Hilcorp Energy Company HALLI BU RTON Ninitchik unit Anticollision Report for Kalotsa 1 -Kalotsa 1 wp04a Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 10.00 8.75 7.50 _ I 6.25 LEGEND - LL 5 5.00 -9- Kalotsa 2,Kalotsa 2,Kalotsa 2 wp03 VO �- Kalotsa 3,Kalotsa 3,Kalotsa 3 wp04 VO I Kalotsa 4,Kalotsa 4,Kalotsa 4 wp04 V0 3.75 $- Kalotsa 1 wp04a 2.50 Collision Avoidance Req —No-Go Zone-Stop Dulling - - 1.25 _ 0.00 liii11111 11111 iii ilii ilii 1111 1111 1111 1111 1111 1111 1 0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 Measued Depth(650 usfVn) 09 November.2016- 16:28 Page 4 of 4 COMPASS RECEIVED STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMISIIN OCT 2 0 2016 PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: 1 h.Proposed Well Class. Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is proposed for: Drill ❑, . Lateral ❑ Stratigraphic Test ❑ Development-Oil 0 Service- Winj ❑ Single Zone ❑., • Coalbed Gas 0 Gas Hydrates ❑ Redrill❑ Reentry ❑_ Exploratory-Oil ❑ Development-Gas CI . Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244. Kalotsa 1 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 8,600' • TVD: 7,492' . Ninilchik Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Bel :./Tyonek Gas Pool Surface: 2082'FSL,429'FWL,Sec 7,T1S,R13W,SM,AK • (SHL)C061505(TPH,BHL)ADL384372 Top of Productive Horizon: 8.Land Use Permit: 13 •pproximate Spud Date: 1052'FNL,1359'FEL,Sec 12,T1S,R14W,SM,AK N/A 11/15/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 760'FNL, 1629'FEL,Sec 12,T1S,R14W,SM,AK C061505-1615 acres/ADL384372-3147 . res 6457'to the 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-209850. y- 2233465 . Zone-4 GL Elevation above MSL(ft): 126.5 • 'to Same Pool: 1,700'to Paxton 8 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Potential Pressu -s in psig(see 20 AAC 25.035) Maximum Hole Angle: 46.4 degrees Downhole: 3401 . Surface: 2652- 18.Casing Program: Specifications Top - Settin! depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 84# J-55 Weld 80' Surface Su-.ce 120' 120' Driven 9-7/8" • 7-5/8" • 29.7# L-80 BTC 1,500' Surface :urface 1,500' - 1,349' - 688 ft3 6-3/4"• 4-1/2" • 12.6# L-80 DWC/C HT 8,600' Surface Surface 8,600' - 7,492' • 1427 ft3 19. PRESENT WELL CONDITION SUMMARY(To be co ,.leted for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length S Cement Volume MD TVD Conductor/Structural Surface i� �q L �j tVf Intermediate ' ` Production i Liner \\.c \L l Perforation Depth MD(ft): , ` Perforation Depth ND(ft): 20. Attachments: Property Plat (r _ BOP Sketch ❑✓ Drilling Program Q Time v.Depth Plot 0Shallow Hazard Analysis❑✓ Z Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Repr=-entative: Date 22.I hereby certify that the foregoing i rue and the procedure approved herein will not be deviated from without prior writte pproval. Contact Email mmyerse,hiIcorp.com Printed Name Mon Myers Title Drilling Engineer Signature ^ Phone 777-8431 Date f0 - 20 - Zo /(o Commission Use Only Permit to Drill ��- 75 — IAPI Number: Permit Approval See cover letter for other Number: 250- /,}3 2 66-Gate: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed ethane,gas hydrates,or gas contained in shat s: Q' Other: . - s5o ,o5 e of t_ Samples req'd: Yes Irigf No❑ Mud log req'd:Yesm-^❑ �;�] �` H2S measures: Yes❑ Non' Directional svy req'd:Yes[ ❑ ' /V t I f - 1.4 C:-oL. /`egj •... -Tur-J Spacing exception req'd: Yes❑ No[J]� Inclination-only svy req'd:Yes No[( a / L Post initial injection MIT req'd:Yes❑ No❑ 'Z /�\)t ve_v'-4- f,`.,34-'- - �"�` ,-,-:-/-......0 /Tz..)1 ,Si-Gr^'_7izc- . k , !l / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: t-/tcr r 6 Submit Form and Form 1 401(Revised 11/2015) T r r�+i ski f�t29 months from the date of approval(20 AAC 25.005(8,),)` Attachments in Duplicate Hilcorp Alaska, LLC P.O. Box 244027 Monty Myers Anchorage, AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Energy Company 10/20/2016 RECEIVED Commissioner OCT 20 2016 Alaska Oil & Gas Conservation Commission AOGCC 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Kalotsa 1 Dear Commissioner, Kalotsa#1 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 268' MD. Maximum hole angle will be 46 deg. and TD of the well will be 8600' TMD/ 7492' TVD, ending with 0 deg inclination left in the hole. Vertical section will be 3058 ft. Drilling operations are expected to commence approximately November 15th 2016. 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 #1 Drilling Program Ninilchik Unit Rev 0 October 14th, 2016 • I Kalotsa#1 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 RJU 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 N/U 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 (wp04) 47 • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 1.0 Well Summary Well Kalotsa#1 • Pad&Old Well Designation Kalotsa#1 is a grass roots well on Kalotsa Pad ' Planned Completion Type 4-1/2"Production tubing Target Reservoir(s) Beluga/Tyonek Planned Well TD,MD/TVD 8,600 MD/7,492' TVD PBTD,MD/TVD 8,500' MD/7,392' TVD Surface Location(Governmental) 2082' FSL,429' FWL, Sec 7, T1S,R13W, SM,AK • Surface Location(NAD 27) X=209850.08,Y=2233445.69 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1052' FNL, 1359' FEL, Sec 12,T1S,R14W, SM,AK TPH Location(NAD 27) X=208089.41,Y=223459.69 TPH Location(NAD 83) BHL(Governmental) 760' FNL, 1629' FEL, Sec 12,T1S,R14W, SM,AK BHL(NAD 27) X=207826.00,Y=2235758.00 BHL(NAD 83) AFE Number 1612639D AFE Drilling Days 4 MOB, 18 DRLG AFE Completion Days AFE Drilling Amount $3,299,072 AFE Completion Amount $400,000 Maximum Anticipated Pressure (Surface) 2652 psi • Maximum Anticipated Pressure (Downhole/Reservoir) 3401 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 Type 82 Single Ram Page 2 Version 0 October, 2016 • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: October 17,2016 Subject: Changes to Approved Permit to Drill for Kalotsa#1 File#: Kalotsa#1 Drilling Program Any modifications to Kalotsa#1 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. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Monty M Myers 10.17.2016 Drilling Engineer Date Page 3 Version 0 October, 2016 • • 111 Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) 6k (psi) (psi) (k-lbs) Cond 16" 15.01" 14.822 17" 84 J-55 Weld 2980 1410 - 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 4790 683 6-3/4" 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 OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 5.0 Internal Reporting Requirements 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@hilcorp.com, Ikeller@hilcorp.com,mmyers@hilcorp.com and cdinger@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!!!! a. John Coston: 0: (907)777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0: (907)777-8317 C: (907)602-5178 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 • Notify Drlg Manager 1. Paul Mazzolini: 0: 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 cdinger@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp.com Page 5 Version 0 October, 2016 • • 111 Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 6.0 Planned Wellbore Schematic Ninil PROPOSED Well Kachiklotsa#2 PTD: 000-000 API: 50-000-00000-00 Illy,, .i4.r.4a.i 7, CASING { DETAIL Q ... /� Mud 16" Size Type Wt Grade Conn. ID Top Btm Weight t" Conductor "". —Driven r.° 16" 84 X-56 Weld 15.01" Surf 120' N/A to Set _ Depth jet:.. 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,500' 8.8 ppg t` DWC/C 4-1/2" Prod Csg 12.6 L-80HT 3.958" Surf 8,600' 9.5 ppg 5`") I 1 7-5/3* + t -41 ... , ...., 1, Drilling Info Hole Section Casing MW Workstrirg a *,°0' 9-7/8" 7-5/8" 8.8 ppg 4-1/2" , ir a 6-3/4" 4-1/2" 9.2-10.5 ppg 4-1/2" t w . "ti 6-3/4" JEWELRY DETAIL Hole �' No. Depth ID OD Item iff; ;...t 1 1,300' 3.958" 6.875" Baker Swell Packer Ofr. .44, :''''i Lt R a Cep TA r,mss �k 3 rA r' K°fi " e 4-1/2" , ., r* PBTD=8.500'/PBTVD-7,392' II)-8.600'/TVD-7,492' Page 6 Version 0 October, 2016 • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary Kalotsa#1 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 268' MD. Maximum hole angle will be 46 deg. and TD of the well will be 8600' TMD/7492' TVD, ending with 0 deg inclination left in the hole. Vertical section will be 3058 ft. Drilling operations are expected to commence approximately November 15th 2016. 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 / 1,349' 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 durinndrilling 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 cmt 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 8,600' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 4-1/2"production casing . 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR+Res LWD. 2. Production Hole: GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. Page 7 Version 0 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Fomar Company 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#1. 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 10/10 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 both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: '-7 c-.) Diverter waiver requested due to the recent drilling of Susan Dionne#2 nearby (4500' away). No issues were experienced while drilling the surface hole. Surface casing for SusanDionne #2 was set at 1570' TVD. Surface casing is requested to be set at 1,349' TVD on Kalotsa#1.No shallow hydrocarbon zones will be penetrated. /<.,,,l t I „i/ i,_ hrs I- a % tf c ' di 6 A. L.U4_i v --r /'t- ee -er 5it..641-4= `1U-- 2" . Page 8 Version 0 October,2016 • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 9-7/8" • No diverter utilized n/a • 11"x 5M 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 2-1/16"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:jim.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/TestWitnessNoti£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 October,2016 . • Kalotsa#1 11 Drilling Procedure Rev 0 Hilcorp Energy Company 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. ) , I4. h 9.7 Mud loggers!; required on surface hole section. 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. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm (100%)with 5-1/2" liners. Page 10 Version 0 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 10.0 N/U 16" Conductor Riser 10.1 N/U 16" Conductor Riser • 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 October, 2016 • Kalotsa#1 11 Drilling Procedure Rev 0 Hilcorp Energy Company 10.3 Rig Orientation on Kalotsa pad: l /' / . 41 k 4r//:: ,(4,/ ,,/ ' --' ---***.........• ---N* 4). --A.: .., \ i //7/r / / \ S 1 f �' // . KALOTSA ,i ( ,,/' / 55);'x,aj .ter` (,,,, l f r, n � �: p`. y bg F* a• „J // 416,,, „....,. ,,,,,,,„ z x 1‘10 \ ',.''':':,,,*'ji:,:s:/'" \#: ,/ .: ,..," . .5 \\\\VX"" — / S 7 i / / / J / Page 12 Version 0 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 11.0 Drill 9-7/8" Hole Section 11.1 P/U 9-7/8" directional drilling assy: • 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 TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 ty 11.2 9-7/8"BHA (GR and Res are included in below BHA): Q�,,,=1 it'd ,, �- 2; 0 ID ', .length Aipumulative �.g; (in) Ill) 1 9-7 3' FDC 6.020 2.250 9.875 8345 F 4-1 2' RE( 0.89 0.89 2 7'SperryDrill Lobe 7+8-7.5 stg 7.000 4.952 95.669 B 4-1>2"IF 30.00 30.89 Stabilizer 9.625. 3 6-34"integral Blade 9 34" 6.760 2 500 9.750 105-59 B 4-1.2"IF 6.99 37.88 4 6-34"Float Sub 6.800 2.375 108.67 B 4-1:2"IF 3.00 40.88 5 6 34"DM Collar(Directional) 6.720 3.125 103.40 B 4-t'2 IF 9.20 50.08 6 6 34"DGR Collar(Gamma) • 6.710 1.920 97.80 B 4-1r2"IF 650 56.58 7 6 3'4"EWR-P4 Collar(Resistivity) . 6.710 2.000 104.30 B 4-1;2"IF 12.00 6858 8 6 3`4"PWD Collar(Pressure) 6 72 1.905 96.30 B 4-1!2"IF 4.44 73-02 9 6 34"HCIM Collar(Processor) 6.750 1.920 101.70 B 4-1,2"IF 6.50 79.52 10 6 3(4"TM Collar(Telemetry) 6.550 3.250 103.60 B 4-1:('2"IF 9.90 89.42 11 6.75"NM Flex Collar 6.450 2.875 89.23 B 4-1(2"IF 30.00 119.42 12 X-Over Sub 4-112 IF x CDS 40 6.450 2.625 92.91 B 4 40 CDS 3.00 122.42 . 13 3 jts 4-1;2"HWDP 4.500 2.813 36.86 93.00 215.42 14 X-Over Sub CDS 40 x 4-1('2 IF 6.300 2.625 87/9 B 4-1,'2"IF 3.00 218.42 15 6-1.'4"Weatherford Jar 6.270 2.250 91.68 8 4-112"IF 30.00 248.42 16 X-Over Sub 4-1:2 IF x CDS 40 6.230 2.625 85.44 B 4.5"CDS40 3.00 251.42 17 5 jts 4-12"HWDP 4.500 2.813 36.86 - 155.00 406.42 01117" ., 406.42 Page 13 Version 0 October, 2016 III • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Enema,Company 11.3 Primary Bit: 9-718' (251mm) MM65 PRODUCT SPECIFICATIONS au Cutter Type Seleeteutter to., tADC Code M323 Body Type MATRIX 1 Total Cutter Count 41t- , III 1P-6, - Cutter Distribution 1/111B1 ,lkaa 0 Foot: 0 2$ Gauge 12 0 Up Drill 6 0 Number of Large Nozzles 6 Number of Medium Nozzles 0 Number ofSinall Nozzles 0 Number of Micro Nozzles 0 * v. 1.,!.T, Number of Peru(Site) 0 Number of Replaceable Potts ISizek 0 Junk Slot Area(sq in) 16.71 Normalized face Volume 45,44% , I6 ,;..7,,,, 1 1,, '-,,=, t.-4a7 1 API Conneetion 4-1,'2 REG.PIN 40 ' Recommended Make-Up Torque* 12,461-17,766 Ft*Ihs. Nominal Dimensions** ,\C•R:): • 1-1-'.' ," Make-Up Face to Nose 10.131 in-275 ram i',..,• Ciange Length 23 in.64 min Sleeve Length 0 in-0 am Shank Diameter 6 in-152 non Break Out Plate 4klat*LegacY0 18145444040 Approximate Shipping Weight 250Lbs.-113Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pods,1116-Relieved Gage Matcriat#771827 •ltit specific recommended makeup torque is a function of the bit ID.and actual bit sub O.D.utilized to iced Bed in API MG Section A.8.2. "Design dimensions are t1011111141 and may vary slightly on numulamtired product Itallibuston Drill 13114 and remakes models are onflt301104441y rommed and relined Product specifications may change without notice. SZi 2013 Hal libarton.All rights reserved_Saks of Halliburton products and services will be in accord solely with the terms and conditions ../ contained in the contrast between Halliburton and the customer that is applicable to the sale. www.halliburtort.com Page 14 Version 0 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 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/ 1,349' 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 API FL pH 120-1500' 8.8—9.5 ' 85-150 20-40 25-45 <10 8.5-9.0 Page 15 Version 0 October, 2016 IP Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company System Formulation: Aquagel + FW spud mud Product Concentration 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. 11.10 No open hole logs are planned for the 9-7/8"hole section. Page 16 Version 0 October, 2016 • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 12.0 Run 7-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 7-5/8" casing running equipment. • 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" 7,630 ft-lbs Page 17 Version 0 October, 2016 11110 Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY Outside Diameter 7.625 in Wall Thickness 0.375 in API Drift Diameter 6.750 in Nominal Weight 29.70 lbs/ft Nominal ID 6.875 in Alternative Drift Diameter n.a. Plain End Weight 29.06 lbs/ft Nominal cross section 8.541 in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Tension Yield 683,000 in Internal Pressure Yield 6,890 psi Collapse Pressure 4,790 psi Available Seamless Yes Available Welded No CONNECTION DATA TYPE:BTC GEOMETRY Coupling Reg OD 8.500 in Threads per in 5 Thread turns make up 1 PERFORMANCE Steel Grade 180 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 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 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 18 Version 0 October, 2016 • • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Enema company 13.0 Cement 7-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • 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+ /o open hole excess. Job will consist of lead& tail, TOC brought to surface. / 04) 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: (1 0' — 120')x .0382 bpf x 7 X44 9-7/8" OH x 7-5/8" Casing /coo 1.5 = 56. ),51-; annulus: � Total LEAD: 9Oi2 5 . 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: Total TAIL: 34.2 bbl 182 ft3 Page 19 Version 0 October, 2016 1364 i i S Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company Cement Slurry Design: Lead Slurry (1000' MD to surface) Tail Slurry (1000' to 1500' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk Additives D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC D046 Anti Foam 0.2% BWOC D065 Dispersant 0.4% BWOC D079 Extender 2.0% BWOC S002 CaCl2 0.35 % BWOC D020 Extender 3.0% BWOC D177 CaCl2 0.1% BWOC 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 October, 2016 Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 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 a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold,pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • 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 success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to cdinger dihilcorp.com and mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 21 Version 0 October, 2016 • Kalotsa#1 Drilling Procedure Rev 0 Energy Hilcorp company 14.0 BOP N/U and Test 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 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • 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 October, 2016 • • Kalotsa #1 111 Drilling Procedure Rev 0 Hilcorp Energy company 15.0 Drill 6-3/4" Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray and Resistivity LWD • functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.7 Workstring will be 4.5" 16.6# S-135 CDS40. Ensure to have enough 4-1/2"DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. Page 23 Version 0 October,2016 S . II Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 15.8 6-3/4" BHA: COMPONENT DATA . item on it G.1,.:f1c^ Wright Top Length Cumulative a Serial Nuo her 4 OM Out crnr oGptt Connect ton (ft) Length {ft) 4.500 '1.563 G.759EaliIMEMINIMMII0.75 ® 5'SperryD-ill Labe 5'7-6 0 s".g 5.004 EMII 18 U9 LIME 24.00 24.75 Slab ter _-_ ii.brAiMI. IIE :+.10,,,1.,ie Stabilize' 4.840 2.000 £i O0 52 00 8 3-lir IF 5 00 32.00 - 4 3;4`DRi Collar 4 71. '.250 47 00 B 3-112"IF 9.20 41.20 ® 4 3+'4'Slim Phase 4 Cellar -1.7 ',.2510 48 2G linEEM 24.50 65.70 ® inline Slabihzer AILS) 4.fe.. ',520 b 13 50 27 LESSIM 3.5U 63.20 NM 4 3."4"AL1)Collar • 11111111111111 4 751) magninaci 8 3,162"1F 83,20 ME Slutx=zer -__ -`".)25 _.1111111--: ® 4 3 4'CTN Collar • 4.750 `.253 50 50 B 3-12"IF 11.03 54.20 10 4 314'FIND • 4.754 1.253 47;30 B 3-1:2"IF 3.20 103.40 ® 41,4 TM HOC Weiser] 4.750 i. 5J 49 9U l 3-1f2"IF 11.00 114 40 Ell 4 Tr HAT Collar • 11.1111111111rEgingumEtzg 6 NC 311 76 42 Nom' ® 4 75"Flex Culla- 4 750 2.253 45 04 Ea= 31.00 171 92 ® 4 75'"Flex Collar 4.750 2.250 46.84 1=1 31.00 202.82 ® X '-1 i2'IF Pin X 4-1.'2 CDS 510 box 5.250 2.25 60..22 'B 4.5'CJS-40 2.75 295 67 16 6 Ja-nts 4-1,2'FfrND1' 4.55 C 2.753 41.00 105.90 390.57 am X o 4 117'CDS 43 fpm X:i 1.7 If boxIIIIIMIIIIIIII 530x• '2 z''i 1M 61 64 393:32 ® 4 3.4"W atherfot0 Fiyrl J.>r IIIIIIIIIIMI an 2.r`5'a M 46.84 8 3 'd"IF e0 5;1 MEM ® X-O 3-1l2"1F Pin X 4-112"CDS-40 Box 5.390 2.750 MI 54.94 =ME 2 77: 421:07 20 13 Joints 4442 H'WDP :.500 2.753 41 00 III 400.00 826 07 Total: 82607 DATA Bit Number Nozzles :6x10 Bit Size (In) : 6.750 TFA (in2} :0.4602 Manutreturer : HOBS Dull Grade In - MQdei : EM65D Dull Grade Out Serial Number Page 24 Version 0 October, 2016 • . Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 15.9 Primary Bit: 6-3/4" (171mm) EM65D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling itrw. TAUC Code M323 Body Type MATRIX Total Cutter Count 13 Cutter Distribution aggl Zit= Face a 13 , Gauge II 0 Up Drill 5 0 10. Number of Large Nozzles 0 Number of Medium Nozzles 0 111* Number aSmall Nozzles 6 Number of Micro Nozzles 0 Number of Punts(Sin) 0 Number of Replaceable Ports(Sim) 0 fli' r Olis '', Junk Slot Area 1 sq int 8.6g0' ' ,,,, Normalized Face Volume 34.69% '4,1 , 4 ae a. API Connection 3-1 1 REG.PIN , . Recommended Make-Up Torque* 5,173—7,665 Pintas. Nominal Dimensions" Make-Up Face to Nose 9.42 in-239 mm Gauge Length 2 in-$1 min Sleeve Length 0 in-0 nn Shank Dianseter 43 in-114 nun Break Out Plate(Mat,glegacya) lfil933/44030 Approximate Shipping Weight 901.N.-41Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads,FW Stepped Gage.Optimized Dual Row-"D"Feature Material#761302 *Bit specific recommended makc-up torque IN a hinctioin of thebit ID.and actual bit sub 0.0.utilized m weciretill in API flP7B Section A.A2. **Design dimensions are Itailtmal and may 41111!slightly cm imunafactured[wisdom.lilallihurion Drill Bits and Senicts°Well arc continuously reviewed and Mired Product ipecificalliwi omv chmlue without tl..41.: c.2013 Hal libation.All rights reserved.Saks of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.com Page 25 Version 0 October, 2016 • • 111 Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 15.10 6-3/4"hole section mud program summary: 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 PUPA fresh water based drilling fluid. Properties: Mud w ,, Plastic : , ' - s -,,vii� sr,:D Weight r ' ,4'' Viscosity -„ ° Pot p '` , 1,500'-8,600' 9.0— 10.0 40-53 15-25 15-25 8.5-9.5 <11.0 System Formulation: 6% KCL EZ Mud DP duct aril'I .`,Atkin{ Water 0.905 bbl KCl 22 ppb (29 K 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 ` ,,/l TOC tagged on AM report. 0/1 15.12 R/U and test casing to 3500 psi/3%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 October,2016 • • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 15.15 Conduct FIT to 12.5 ppg EMW. Note: Offset field test data predicts frac gradient at the 7-5/8"shoe to be between 11 - 13 ppg EMW. An 12.5 ppg FIT results in a 3 ppg kick margin while drilling with the planned MW of 9.5 ppg. Kick tolerance = (12.5-9.5)X(1349/7492) = 0.54 15.16 Drill 6-3/4" hole section to 8,600' MD/ 7,492' 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 other stand drilled. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and QFT 2 analysis for Lower Tyonek to total depth. 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 run and log well. 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 Install 4-1/2"pipe rams in BOP stack and RU and test. Page 27 Version 0 October, 2016 I • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 16.0 Run 4-1/2" Production Casing 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 M/11 torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5,800 ft-lbs 6,500 ft-lbs 7,200 ft-lbs Page 28 Version 0 October, 2016 • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Tubing 4-1/2 in 12.60 lb/ft(0.271 in) L-80 standard Material 4 L-80 Grade 80,000 Minimum Yield Strength (psi) IIIIIIIIIIIIIIIIIIIIIIIIINVUSA 95,000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston.TX 77041 Phone:713-479-3200 4.500 Nominal Pipe Body O.D. (in) Fax:713-479-3234 3.958 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsaies(a?vam-usa.com 0.271 Nominal Wall Thickness(in) 12.60 Nominal Weight (lbs/ft) 12.25 Plain End Weight(lbs/ft) 3.600 Nominal Pipe Body Area (sq in) : Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (lbs) ) 7,500 Minimum Collapse Pressure (psi) 8,430 Minimum Internal Yield Pressure(psi) 7,700 Hydrostatic Test Pressure (psi) °sj 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) a 3.600 Critical Area (sq in) . 100.0 Joint Efficiency(%) Connection Performance Properties 288,000 Joint Strength (lbs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (lbs) 288,000 Compression Rating (lbs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] a Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-lbs) 0040414444 6,500 Maximum Final Torque (ft-lbs) 7,200 Connection Yield Torque (ft-lbs) Page 29 Version 0 October, 2016 ! ! li Kalotsa#1 Drilling Procedure Rev 0 orp ra Company 16.6. Run in hole w/4-1/2" casing to the 7-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. a, I�9'16.12. PU 4-1/2"X 6-3/4" swell packer to be placed at approximately 1300 . Swell packer should have '-'3‘I a" 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 30 Version 0 October,2016 • • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Eno.comer 17.0 Cement 4-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • 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 pump. • 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 10.5 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: (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: (8600— 1500) x 0.025 x 1.35 = 240 1345 Shoe Track: 80' x 0.019 = 1.5 8.5 Total Volume : 254.5 1427 5`x Page 31 Version 0 October, 2016 • • 11 Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 17.7. Drop wiper plug and displace with 3%KC1. 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 1/2 shoe track. Shoe track volume is 1.5 bbls. ✓ 17.12. Bleed pressure to zero to check float equipment. Watch for flow.Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. D;•>e g-- 0,63, o 3 9,5 17.14. WOC minimum of 12 hours, test casing to 3500 psi and chart for 30 minutes. t Z Lfr' Ensure to report the following on wellez: 71( • 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 success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 32 Version 0 October, 2016 • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 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 n c -) .ice . C( L le ✓ e-JY C--1-2-6A-4- 111" E 7i' ' / (*, Page 33 Version 0 October, 2016 a • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Enccgy Company 19.0 BOP Schematic lit lit til lil tit III Iiia fit 3.5' 1. / VI— Medet60111 11"-500D '—IWiftIfftliftf 1111 LA Model 7087 t, l f, # 11"..5001 u � y IIIIIIIIIIIIII MINS "111 9! 'I1! 4 ,J�.' II+x+; II _ 0411l: U$1.1111.1.11111116.1111 '- 2 1/16 --_21/16 5M Kilt Side' t 1/8 5M Choke Side T 1.41' aik Modef7't?82 ...4 Awir-II in a tII Ill III I#I 4;rod,_ ...-. 2.00' iii Ili Ililii lit 1 ,I 1 mummumma a a : / 1 or 1" sir II I - 1.0 ..t 20' 5/s" 1" Page 34 Version 0 October, 2016 fa ill Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 20.0 Wellhead Schematic Ninikhik Unit Casing hanger,CW,11 x 4 Y, Kalotsa al and 2 DWUt box btm x 6.125"RH 16x75/8.4 Y: stub acme box top,w/75/8 od neck,4"type H BPV profile,00-Nt material BMA Otis,41/165M FE x 6.5 Otis quick union top f I L--. • xrs ,;Valve,Swab,WKM.M 4 1/16 SM FE.HWO, i EE trim (�� ' 4 ...._,4iCalis Valve,Wing,WKM-M. L 41 Valve, 31/85M FE,HWO, man EEtram i:Sii; MIMI ■ ; ratan i Valve,Upper matter, WKM.M, �' "\(a 41/16 SM FE,HWO,EE tam ,, 4(111110 medias,Muir 111111.1111011 m Valve,Master,WKM•M, 4 1/16 5M FE,HWO, M11 '4 EE trim III-rat 11111 11111 11111111111111111 Tubing head,Cactus C-291- _� HPS,135/85M x 11 SM,w/ xar 17=4 ' 2-21/16 SM 550 I aiilaill mat 1, 1,, __ley. Starting head,Cactus C-291, -a r •' I 13 S/SSM x 16 SOW,w/2-2 — Z • t' R-44- 1/16 SM SSO 1111 NMI ISit L 6K 16'. 7 5/8" Page 35 Version 0 October, 2016 • • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp EnexgY Company 21.0 Days Vs Depth Days Vs Depth 0 Kalotsa#1 1000 —KBU31-06X 2000 3000 4000 CL v -o -o 5000 ar 2 6000 7000 8000 • 9000 10000 0 S 10 15 20 25 Days Page 36 Version 0 October, 2016 • • 11 , Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: Kalotsa 1 FIELD: Ninilchik(Pax-Dionne Area) SURFACE LOCATION X=209,850.08 BHL: X=207,826.00 AFE: (PROPOSED): Y=2,233,465.69 Y=2,235,758.00 PAD ID Kalotsa 1 COORD REF.SYSTEM NAD27 AK4 True North EST.KB: 144.5 PROPOSED TD: 8,600'MD 7,492'TVD Rig RKB: 18 Saxon 169 API: TBD EST.GL: 126.5 Drill an 8600 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 FORMATION TOPS 8 GEOHAZARDS EXPECTED FLUID MD TVD(FT) SUBSEA DEPTH Est.Pressure EMW Beluga 120 gas 4352.57 3,356.50 -3212.00 iiiik,1510.425 8.7 Beluga 135 gas 4564.61 3,533.50 -3389.00 '1590.075 8.7 Tyonek TX gas 4661.90 3,617.50 -3473.00 '1627.875 8.7 Tyonek T3 gas 4850.10 3,784.50 -3640.00 1703.025 8.7 Tyonek T6 gas 5144.88 4,056.50 -3912.00 lir1825.425 8.7 Tyonek 65 g 7501.07 6,393.50 -6249.00 2877.075 8.7 Tyonek 83 ga 7800.07 6,692.50 -6548.00 3011.625 8.7 Tyonek 90 gas 7976.07 6,868.50 -6724.00 3090.825 8.7 Tyonek 110 gas 8274.07 7,166.50 -7022.00 3224.925 8.7 Tyonek 140 gas 8545.07 7,437.50 -7293.00 3346.875 8.7 Reservoir Objectives =Possible Geo Hazards DATA COLLECTION REQUIREMENTS: Mud Logging: Surface Csg.To TD,samples collected at 20'intervals • LWD Data LWD Triple Combo from surface casing to TD • Other Log Data: COMPLETION TY ter,. ... .. �, NOTES Chance of Success&Anticipated Rateit 95% ARTIFICIAL LIFT EQUIPMENT OD 16" 136' PROSED PIPE SET DEPTHS 7" L. 1500' 4-1/2" - TUBING SIZE -IIII OTHER COMMENTS NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HILCORP OR THEIR PARTNERS. Page 37 Version 0 October, 2016 • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 23.0 Anticipated Drilling Hazards 9-7/8" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 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 intial 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 October, 2016 Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Emmy Company 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 btwn 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%KC1 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: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. • Page 39 Version 0 October, 2016 • 0 II Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 24.0 Saxon Rig 169 Layout tHHIEA FFF 1..,5 = J DrwlVi ■lyu�. IIII VIII � ��-� -�� FF:FTk IIIIII N ; p er.�i��I 1' P 1 0,I :%„4,,=...j."." - �IVI■n IY I�I -HAIF rte. a Fai. `Ir as � �i�irniGi■iv��r�a } W - _-_I� F3-YM1 Pak MEMf _-- -117-1- 111 — — III ,i=.is Mir-INIM IN r �wtFc F--nKU iiI 1E1 ,411 1, .. IIIIIIII� -- -lilullul EL 4�. .._--a u ---J 1c� 'ill � II `'1 il ® 1 [ de luImmo _A_______4 , —'— ] p ....... win -- IIIL. a I efflfl _ : ._ _ Page 40 Version 0 October,2016 • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 41 Version 0 October, 2016 0 0 Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 26.0 Choke Manifold Schematic r`1* 5. 1 Fr. _ k4 r l �t._. C V ...�...t.��. Ow.' y. . v v * , ' ...... V ,'-_ y E a I 4„1 *4 144:-.-441$ -1-mg! r II 1 am 11. F 6 iii44. / MA P. ,M , 21, it := l 2 :. S 1 wig . 4A, i' 1 a MST _ moi__ ... a 1.r V a ; a i;'v y7 I._ u 03: 1�1i L7' m ci .ra e.,“. .,n e 9 .I � �1 , $ '. - dl : C.ell I i iiiima I ammo P ., a,0 e t 10f + 1 __,L. 111411141b 11 1-AAA' : 11: -: Pit ;(1.'01111 1 Pr ir Cr IP ii _ _ 10 P Pka1 a Page 42 Version 0 October, 2016 • Kalotsa#1 Drilling Procedure Rev 0 Hilcorp Energy Company 27.0 Casing Design Information Calculation & Casing Design Factors Ninilchik DATE: 10/17/2016 WELL: Kalotsa #1 FIELD: Ninilchik DESIGN BY: Monty M Myers Design Criteria: Hole Size 9-7/8" Mud Density: 8.8 ppg Hole Size 6-3/4" Mud Density: 10 ppg Hole Size Mud Density: Drilling Mode MASP: 2652 psi (see attached MASP determination & calculation) • MASP: Production Mode MASP: 3401 psi (see attached MASP determination& calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.454 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 1 4 Casing OD 7-5/8" 4-1/2" Top(MD) 0 0 Top(TVD) 00 Bottom (MD) 1,500 8,600 Bottom (TVD) 1,355 7,492 Length 1,500 8,600 Weight(ppf) 29.7 12.6 Grade L-80 L-80 Connection BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 44,550 108,360 Tension at Top of Section(lbs) 44,550 108,360 Min strength Tension (1000 lbs) 683 288 Worst Case Safety Factor(Tension) 15.33 , 2.66 Collapse Pressure at bottom (Psi) 589 3,259 Collapse Resistance w/o tension (Psi) 4,790 7,480 Worst Case Safety Factor(Collapse) 8.13 2.30 MASP (psi) 455 2,652 Minimum Yield (psi) 6,890 8,430 Worst case safety factor(Burst) 15.14 3.18 Page 43 Version 0 October, 2016 i • Kalotsa #1 Drilling Procedure Rev 0 Hilcorp Energy Company 28.0 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation xilcor- 6-3/4"Hole Section "' Kalotsa#1 Ninilchik MD ND Planned Top: 0 0 Planned TD: 8600 7492 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Beluga 120 3356.5 3500.0 Gas Beluga 135 3533.5 1590.1 Gas 8.7 0.450 Tyonek TX 3617.5 1627.9 Gas 8.7 0.450 Tyonek T3 3784.5 1703.0 Gas 8.7 0.450 Tyonek T6 4056.5 1825.4 Gas 8.7 0.450 Tyonek 65 6393.5 2877.1 Gas 8.7 0.450 Tyonek 83 6692.5 3011.6 Gas 8.7 0.450 Tyonek 90 6868.5 3090.8 Gas 8.7 0.450 Tyonek 110 7166.5 3224.9 Gas 8.7 0.450 Tyonek 140 7437.5 3346.9 Gas 8.7 0.450 TD 7492 3400.0 Gas 8.7 0.454 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Susan Dionne 5 9.5-9.8 ppg 1,299' 7,987' 2006 Susan Dionne 6 9.2-9.6 ppg _ 1,578' 4,520' 2008 - Susan Dionne 7 9.2-10.1 ppg 1,450' 7,882' 2011 Assumptions: 1. Fracture gradient at shoe(1355'ND)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: ND Frac Grad 1355 ft X 0.884 psi/ft 1198 psi 1198(psi)-[0.1(psi/ft)*1355(ft)]= 1062 psi MASP from pore pressure during production mode(Complete evacuation to gas) 7492 ft X0.454 psi/ft 3401 psi Downhole 3401(psi)-[0.1(psi/ft)*7492(ft)]= 2652 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 to gas Page 44 Version 0 October, 2016 • 0 Kalotsa #1 Drilling Procedure Rev 0 Hi1C0110 Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) , MONNE I BFIL• g 0 ., _ ..,DIONNE 4 BM - z +/KaloNa I IIII DION" 8 SNOB' , • \ DIONNE 6 BHL• PAXTON 9 BFiL , p0 K.11,,t,..: o ADL384372 00 0 1 . 0 00 0AXTON 4 0 HL• 0 00 00 PAXTON 8 BHLO 0 0 I 00 , 000 C061505 . 1 0,, DIONNE 5 81-111, ' gaOn SOO1S014W NINILCHIK UNIT ct\z Kal,,!,a I Slit. i 1KMotsa Pad 1 I / / ,' ' Legend ; Kaiotsa 1_SHL , f TPH Kalotsa 1 _ i ? 1 , / / -+- Kalotsa 1 BHL _ 1 r-r / / PAXTON 2 BHL/ , i 1 / • Other Surface Wet Locations k 1 t ; 1 , t I ' , NINILCHIK2 • Other Bottom Hole Locations 1 ti / 1 / I I I i ,, Well Paths r r I / DIONNE 7 BHUD/ A i i i it 1 r---1 Oil and Gas Unit Boundary q 11 1 / ,till, / i‘vvnak TON 5 BHL ,10/ f •TL1/ C060385 ADL384372 C060385 1?axton Pad OD siD C060385 C060385 ADL392657 I 11 Ninilchik Unit Kalotsa 1 r, tom Feet Alaska Slate Plane Zone!,NAD27 2 C.CC iiiirturp Alaska.LLC Map Dale:10117/2016 Page 45 Version 0 October, 2016 Kalotsa #1 Ili Drilling Procedure Rev 0 Hilcorp Energy Company 30.0 Surface Plat (NAD 27) • Y �..J r rya !i /,% GOVT LOT 2 •cC MD 3 31 AWN MON, ��Q� .- ' 4725-5 1965 1 GOY'T LOT 3 %/F4 ,./.6 �/ /• KALOTSA PAD I / I / KALOTSA #1 429' FWL , AS STAKED POSITION R LAT: 60' 06'14.78145"N I 1;---- & LON: 151' 35' 24.38031"W n N: 2233465.693' - E: 209850.084' • no 429' FWL - KR 1 KN $5-129 2082' FSL • GOVT LOT 1 zz ASP ZONE 4 NAD 27 • I ELEV: 126.5' (NGVD29) i • w • In 2082' FSL (NT 1 1 FM)2•BRASS CAPiI USCLO 1519 i • • _ SECTION 07 T1S R13W (NTS) I , SECTION 18 T1S R13W (NTS) NOTES 1.BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS AN OPUS 1 SOLUTION FROM NGS COORDINATES STATIONS'KENS CORS ARP","'SEA CONS ARP".AND"ZAN1 WAAS 1 CONS ARP"TO ESTABLISH THE POSITION OF'010 3"ON %%%%V11\ SUSAN DIONNE PAD.THE GEODETIC POSITION OF 010 3 WAS DETERMINED TO '�% O F 11! HAVE A LATITUDE OF 60"06'43.995"N AND A LONGITUDE OF 151'134.35..172"W,THE 4...,__.,...,_ 4.'...—..�lL.q �� ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE A,R;: S.f-�!______ t, N42236337.935 -* •.1.*0, £41352842.572 `�/'�/,�J�,/ ELEV..139.79'(NGV029) ,.. r IY':tCC.e.!(RXIUQw•.••� 2.BASIS OF VERTICAL CONTROL IS NGS BM V82 PID 770586 LOCATED AT MILEPOST �(� I� $TAN A M tA*:E i 127.6 OF THE STERLING HIGHWAY HAVING AN ELEVATION OF 283.59 FEET NGVD29 aa,ts ,� ACCORDING TO NGS PUBLISHED DATA. SCALE �� ~•'l7/05/}f 0 200 400 ',II4 \\\., \\ ," 3.COORDINATE CONVERSIONS(NAD83 TO NAD27)WERE DONE USING CORPSCON I I I I I ``SOFTWARE VERSION 6.0.1. FEET I'I''dd''' HILCORP ALASKA,LLC Ai,4, KALOTSA#1 VAN' NV`"N AclAtt. NINILCHIK ALASKA :44"`Ye KR 'MOW sfAS STAKED SURFACE LOCATION1 P4a4t. c Ir.'z 1,414,4141NN,MAPPIKKid SUFNMYN4GITESTING NAD 27 SOON NO N4. P 0 800 400 00.0010k 40.WWI I(SUAII kt wxF 10000 2C0 FAX{440,2434245 SEC.07 T01S R13W sr<Ev EWA,. Sd1C,ANE,ONC,NNECG CPN Iloleorp Al,RSI:A"LLC ca 1 SEWARD MERIDIAN,ALASKA Page 46 Version 0 October, 2016 • s Kalotsa#1 Drilling Procedure Rev Hileorp Energy Company 31.0 Directional Plan (wpO4) Page 47 Version 0 October, 2016 • • Hilcorp Energy Company Ninilchik Unit Kalotsa Kalotsa 1 Kalotsa 1 Plan: Kalotsa 1 wN 04 Ix : ,-,:: Standard Proposal Report 20 October, 2016 4 4 pl 10 ill HALLIBURTON imiliiiiiiiminom Sperry Drilling Services HAL.LEBURTON Hilcorp Energy Company • REFERENCE INFORMATION IIIp HIlcorCalculation Method: Minimum Curvature Co-ordinate(N/E)Reference: Well Kalotsa 1,True North Sperry Drilling j' Error System: ISCWSA Vertical(ND)Reference: Kalotsa 1 wp04 @ 144.50usft Scan Method: Closest Approach 3D Measured Depth Reference: Kalotsa 1 wp04 @ 144.50usft Error Surface: Elliptical Conic Project: Ninilchik Unit Warning Method: Error Ratio Calculation Method: Minimum Curvature Site: Kalotsa SECTION DETAILS Well: Kalotsa 1 Wellbore: Kalotsa 1 Sec MD Inc Azi TVD +NI-S +E/-W Dleg TFace VSect Target Design: Kalotsa 1 w p 04 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 92 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 3 1411.72 46.47 317.23 1288.49 327.28 -302.75 4.00 317.23 445.84 4 3784.93 46.47 317.23 2923.02 1590.34 -1471.11 0.00 0.00 2166.41 5 6108.37 0.00 0.00 5000.00 2244.90 -2076.60 2.00 180.00 3058.08 6 7502.87 0.00 0.00 6394.50 2244.90 -2076.60 0.00 0.00 3058.08 K-1 wp01 T65 Tgt2 DDI = 5.620 7 8600.00 0.00 0.00 7491.63 2244.90 -2076.60 0.00 0.00 3058.08 CASING DETAILS WELL DETAILS: Kalotsa 1 TVD TVDSS MD Size Name Ground Level: 126.50 1349.29 1204.79 1500.00 7-5/8 7 5/8" +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2233465.69 209850.08 60.104106°N 151.590106°W 7491.63 7347.13 8600.00 4-1/2 4 1/2" I SURVEY PROGRAM Date:2016-08-08T00:00:00 Validated:Yes Version: Depth From Depth To Survey/Plan Tool 18.00 1500.00 Kalotsa 1 wp04 MWD+SC+sag 1500.00 8600.00 Kalotsa 1 wp04 MWD+SC+sag -750-- Start Dir 4°/100':250'MD,250'TVD FORMATION TOP DETAILS -a TVDPath TVDssPath MDPath Formation 0-I - 3356.50 3212.00 4357.98 Beluga 120 -- 3533.50 3389.00 4568.83 Beluga 135 3617.50 3473.00 4665.66 Tyonek TX 500 End Dir :1411.72'MD,1288.49'TVD 3784.50 3640.00 4853.09 Tyonek T3 4056.50 3912.00 5146.93 Tyonek T6 6393.50 6249.00 7501.87 Tyonek 65 750-, 1000 6692.50 6548.00 7800.87 Tyonek 83 O. 6868.50 6724.00 7976.87 Tyonek 90 ^43 7166.50 7022.00 8274.87 Tyonek 110 7 5/8"-�. O 7437.50 7293.00 8545.87 Tyonek 140 1500 O9' 1 90 CPStart Dir 2°/100':3784.93'MD,2923.02'TVD `L� DO 2250-- ^b �O c „30 S O� 0 3000- A.P - Beluga 120 o o - - 0 , Beluga 133 R50 r 3750-- Tyonek TX- .5000 a - a) a Tyonek T3 K-1 wp01_T3 Tgt1 - 5500 r 4500--Tyonek T6 CD - 00 2 6---- End Dir :6108.37'MD,5000'TVD I- 5250- 6500 5250- 6500 ° 6000- K-1 wp01 T65 Tgt'7000 Tyonek 65 K-1 wp01 T83 Tgt3. 500 T- yonek 83 K-1 wp01 T90 Tgt4 6750- -- -- .000 -~ Tyonek 90 -` 4 1/2" Tyonek 11Q _Total Depth:8600'MD,7491.63'TVD 7500-`-- 8600 - Tyonek 140 Kalotsa 1 wp04 8250 9000- Iii I I i I I I I I I I I I I I I I I 1 I TI TTS 1111 ] I I I I I I IT7-T . . 1I----_ , I I I i I I 1 1TTi-T r r I-.I-......i I -1500 -750 0 750 1500 2250 3000 3750 4500 525016000 6750 7500 8250 9000 Vertical Section at 317.23°(1500 usft/in) III • HALL-MURTON Project: Ninilchik Unit COMPANY DETAILS:Hilcorp Energy Company WELL DETAILS:Kola..I __ 11 I 1j1(1)11) Site: Kalotsa Calculation Method:Minimum Curvature Ground Levet 126.50 Span'./o'NRe g Well: Kalotsa 1 Error System'ISCWSA +N/-S +E/-W Northing Eastlog Isettude Longitude Scan Method:Closest Approach 3D 0.00 0.00 2233465.69 209850.08 60.104106°N 151.5901064W Wellbore: Kalotsa 1 Error Surface:Elliptical Conic 2700— Plan: Kalotsa 1 wp04 Warning Method:Error Rash REFERENCE INFORMATION Coordinate(N/E)Reference:Well Kalotsa 1,True North Vertical(ND)Reference:Kalotsa 1 wp04 144.50usft Measured Depth Reference:Kalotsa 1 wp04 @ 144.Sousft - Total Depth 8600140,7491.63'7VD Calculation Method:Minimum Cravature 2475— K-1 wp01 T90 Tgt4 4 - Kabta 1 wp04 K-1 wp01 783 TgI3 2250— i_�� K-1 wp01 765 Tgl2 �-pr1T�-__ - to End Dr:6108.37 MD,5000i TVD 4tI2 yo e 2025— Ay5 - 5o SURVEY PROGRAM 1� 1800— Date:2018-08-08T00:00:00 Validated:Yes Version: Start Dr2°/10d:3784.93'MD,2923.02TVD Depth From Depth To Survey/Plan Tool cP� - 18.00 1500.00 Kalotsa 1 wp04 MWD+SC+aag 1500.00 8600.00 Kalotsa 1 wp04 MWD+SC+Seg 1575— ii\''o o - , CASING DETAILS o - K-1 wp01 73 7gt1 v1350— ND TVDSS MD Size Name - e 1349.29 1204.79 1500.00 7-5/8 7 5/8" }G 7491.83 7347.13 8600.00 4-1/2 412' L 1125— ry,C 7 0 w 675- - F d Dir:1411.72'MD,1288.49'TVD ,'S}1 450- - 7us---i1'''ryyo Start Dir 4°/100':250'MD,250TVD 225— o0 �o 0— r -225- 1 I l I i I I i I i I I I I i l i I I i I I I l i I l l t I l l I I i I I i I I I I I i I I t I i I I i I I I l I l I I I l I I l I I i I i I I I I I I I 1 I i I I l l I I l I I l I I I i -2250 -2025 -1800 -1575 -1350 -1125 -900 -675 -450 -225 0 225 450 675 900 1125 1350 1575 West(-)/East(4-)(450 usft/in) • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company TVD Reference: Kalotsa 1 wp04 @ 144.50usft - Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature • Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04 Project Ninilchik Unit Map System: US State Plane 1927(Exact solution) . System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) , Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kalotsa Site Position: Northing: 2,233,465.69 usft Latitude: 60.104106°N%' From: Map Easting: 209,850.08usft Longitude: 151.590106°W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.38° Well Kalotsa 1 Well Position +NI-S 0.00 usft Northing: 2,233,465.69 usft - Latitude: 60.104106°N +EI-W 0.00 usft Easting: 209,850.08 usft- Longitude: 151.590106°W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: , 126.50 usft Wellbore Kalotsa 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength l°1 (°) (nT) I BGGM2013 8/8/2016 15.94 73.13 55,161 I JI Design Kalotsa 1 wp04 Audit Notes: As-Staked Coords used in updated wp Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) I -2.50 0.00 0.00 317.23 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +EI-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 18.00 0.00 0.00 18.00 -126.50 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 105.50 0.00 0.00 0.00 0.00 0.00 0.00 1,411.72 46.47 317.23 1,288.49 1,143.99 327.28 -302.75 4.00 4.00 0.00 317.23 3,784.93 46.47 317.23 2,923.02 2,778.52 1,590.34 -1,471.11 0.00 0.00 0.00 0.00 6,108.37 0.00 0.00 5,000.00 4,855.50 2,244.90 -2,076.60 2.00 -2.00 0.00 180.00 7,502.87 0.00 0.00 6,394.50 6,250.00 2,244.90 -2,076.60 0.00 0.00 0.00 0.00 8,600.00 0.00 0.00 7,491.63 7,347.13 2,244.90 -2,076.60 0.00 0.00 0.00 0.00 10/20/2016 2:28:31PM Page 2 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company TVD Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -126.50 18.00 0.00 0.00 18.00 -126.50 0.00 0.00 2,233,465.69 209,850.08 0.00 0.00 100.00 0.00 0.00 100.00 -44.50 0.00 0.00 2,233,465.69 209,850.08 0.00 0.00 200.00 0.00 0.00 200.00 55.50 0.00 0.00 2,233,465.69 209,850.08 0.00 0.00 250.00 0.00 0.00 250.00 105.50 0.00 0.00 2,233,465.69 209,850.08 0.00 0.00 Start Dir 4°/100':250'MD,250'TVD 300.00 2.00 317.23 299.99 155.49 0.64 -0.59 2,233,466.35 209,849.51 4.00 0.87 400.00 6.00 317.23 399.73 255.23 5.76 -5.33 2,233,471.58 209,844.90 4.00 7.85 500.00 10.00 317.23 498.73 354.23 15.97 -14.78 2,233,482.02 209,835.70 4.00 21.76 600.00 14.00 317.23 596.53 452.03 31.23 -28.89 2,233,497.61 209,821.95 4.00 42.55 700,00 18.00 317.23 692.63 548.13 51.46 -47.61 2,233,518.29 209,803.73 4.00 70.11 800.00 22.00 317.23 786.58 642.08 76.57 -70.83 2,233,543.94 209,781.12 4.00 104.30 900.00 26.00 317.23 877.92 733.42 106.42 -98.44 2,233,574.45 209,754.23 4.00 144.97 1,000.00 30.00 317.23 966.20 821.70 140.87 -130.31 2,233,609.66 209,723.20 4.00 191.90 1,100.00 34.00 317.23 1,050.98 906.48 179.77 -166.29 2,233,649.41 209,688.17 4.00 244.89 1,200.00 38.00 317.23 1,131.87 987.37 222.91 -206.20 2,233,693.50 209,649.31 4.00 303.65 1,300.00 42.00 317.23 1,208.46 1,063.96 270.08 -249.84 2,233,741.71 209,606.82 4.00 367.92 1,400.00 46.00 317.23 1,280.38 1,135.88 321.07 -297.00 2,233,793.81 209,560.90 4.00 437.37 1,411.72 46.47 317.23 1,288.49 1,143.99 327.28 -302.75 2,233,800.16 209,555.30 4.00 445.83 End Dir :1411.72'MD,1288.49'ND 1,500.00 46.47 317.23 1,349.29 1,204.79 374.27 -346.21 2,233,848.18 209,512.98 0.00 509.84 7 5/8" 1,600.00 46.47 317.23 1,418.16 1,273.66 427.49 -395.44 2,233,902.57 209,465.05 0.00 582.34 1,700.00 46.47 317.23 1,487.04 1,342.54 480.71 -444.67 2,233,956.96 209,417.11 0.00 654.84 1,800.00 46.47 317.23 1,555.91 1,411.41 533.93 -493.90 2,234,011.35 209,369.17 0.00 727.34 1,900.00 46.47 317.23 1,624.79 1,480.29 587.15 -543.13 2,234,065.74 209,321.24 0.00 799.84 2,000.00 46.47 317.23 1,693.66 1,549.16 640.37 -592.36 2,234,120.13 209,273.30 0.00 872.34 2,100.00 46.47 317.23 1,762.54 1,618.04 693.59 -641.60 2,234,174.52 209,225.36 0.00 944.84 2,200.00 46.47 317.23 1,831.41 1,686.91 746.82 -690.83 2,234,228.91 209,177.43 0.00 1,017.34 2,300.00 46.47 317.23 1,900.29 1,755.79 800.04 -740.06 2,234,283.30 209,129.49 0.00 1,089.84 2,400.00 46.47 317.23 1,969.16 1,824.66 853.26 -789.29 2,234,337.69 209,081.55 0.00 1,162.34 2,500.00 46.47 317.23 2,038.03 1,893.53 906.48 -838.52 2,234,392.08 209,033.62 0.00 1,234.84 2,600.00 46.47 317.23 2,106.91 1,962.41 959.70 -887.75 2,234,446.47 208,985.68 0.00 1,307.34 2,700.00 46.47 317.23 2,175.78 2,031.28 1,012.92 -936.99 2,234,500.86 208,937.74 0.00 1,379.84 2,800.00 46.47 317.23 2,244.66 2,100.16 1,066.14 -986.22 2,234,555.25 208,889.81 0.00 1,452.34 2,900.00 46.47 317.23 2,313.53 2,169.03 1,119.37 -1,035.45 2,234,609.64 208,841.87 0.00 1,524.84 3,000.00 46.47 317.23 2,382.41 2,237.91 1,172.59 -1,084.68 2,234,664.03 208,793.93 0.00 1,597.34 3,100.00 46.47 317.23 2,451.28 2,306.78 1,225.81 -1,133.91 2,234,718.42 208,746.00 0.00 1,669.84 3,200.00 46.47 317.23 2,520.16 2,375.66 1,279.03 -1,183.14 2,234,772.81 208,698.06 0.00 1,742.34 3,300.00 46.47 317.23 2,589.03 2,444.53 1,332.25 -1,232.37 2,234,827.20 208,650.12 0.00 1,814.84 3,400.00 46.47 317.23 2,657.91 2,513.41 1,385.47 -1,281.61 2,234,881.59 208,602.19 0.00 1,887.34 3,500.00 46.47 317.23 2,726.78 2,582.28 1,438.70 -1,330.84 2,234,935.99 208,554.25 0.00 1,959.84 3,600.00 46.47 317.23 2,795.66 2,651.16 1,491.92 -1,380.07 2,234,990.38 208,506.32 0.00 2,032.34 3,700.00 46.47 317.23 2,864.53 2,720.03 1,545.14 -1,429.30 2,235,044.77 208,458.38 0.00 2,104.84 3,784.93 46.47 317.23 2,923.03 2,778.53 1,590.34 -1,471.11 2,235,090.96 208,417.67 0.00 2,166.41 Start Dir 2°/100':3784.93'MD,2923.02'ND 10/20/2016 2:28:31PM Page 3 COMPASS 5000.1 Build 81 • • Halliburton HALLIE3URTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company TVD Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +EJ-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 2,788.93 3,800.00 46.17 317.23 2,933.43 2,788.93 1,598.34 -1,478.51 2,235,099.14 208,410.46 2.00 2,177.31 3,900.00 44.17 317.23 3,003.93 2,859.43 1,650.40 -1,526.67 2,235,152.34 208,363.57 2.00 2,248.23 4,000.00 42.17 317.23 3,076.87 2,932.37 1,700.62 -1,573.12 2,235,203.66 208,318.34 2.00 2,316.64 4,100.00 40.17 317.23 3,152.14 3,007.64 1,748.94 -1,617.82 2,235,253.04 208,274.82 2.00 2,382.46 4,200.00 38.17 317.23 3,229.67 3,085.17 1,795.30 -1,660.70 2,235,300.42 208,233.06 2.00 2,445.62 4,300.00 36.17 317.23 3,309.35 3,164.85 1,839.64 -1,701.73 2,235,345.74 208,193.12 2.00 2,506.03 4,357.98 35.01 317.23 3,356.50 3,212.00 1,864.41 -1,724.64 2,235,371.05 208,170.81 2.00 2,539.77 Beluga 120 4,400.00 34.17 317.23 3,391.09 3,246.59 1,881.92 -1,740.84 2,235,388.95 208,155.04 2.00 2,563.62 4,500.00 32.17 317.23 3,474.80 3,330.30 1,922.08 -1,777.99 2,235,429.99 208,118.87 2.00 2,618.33 4,568.83 30.79 317.23 3,533.50 3,389.00 1,948.47 -1,802.39 2,235,456.95 208,095.10 2.00 2,654.27 Beluga 135 4,600.00 30.17 317.23 3,560.36 3,415.86 1,960.07 -1,813.13 2,235,468.81 208,084.65 2.00 2,670.08 4,665.66 28.85 317.23 3,617.50 3,473.00 1,983.82 -1,835.09 2,235,493.08 208,063.26 2.00 2,702.42 Tyonek TX 4,700.00 28.17 317.23 3,647.67 3,503.17 1,995.85 -1,846.22 2,235,505.37 208,052.42 2.00 2,718.81 4,800.00 26.17 317.23 3,736.64 3,592.14 2,029.36 -1,877.22 2,235,539.63 208,022.24 2.00 2,764.47 4,853.09 25.11 317.23 3,784.50 3,640.00 2,046.23 -1,892.82 2,235,556.86 208,007.05 2.00 2,787.44 Tyonek T3 4,900.00 24.17 317.23 3,827.14 3,682.64 2,060.58 -1,906.10 2,235,571.53 207,994.12 2.00 2,806.99 5,000.00 22.17 317.23 3,919.07 3,774.57 2,089.46 -1,932.81 2,235,601.04 207,968.11 2.00 2,846.33 5,100.00 20.17 317.23 4,012.32 3,867.82 2,115.97 -1,957.33 2,235,628.13 207,944.23 2.00 2,882.44 5,146.93 19.23 317.23 4,056.50 3,912.00 2,127.58 -1,968.07 2,235,640.00 207,933.78 2.00 2,898.26 Tyonek T6 5,200.00 18.17 317.23 4,106.77 3,962.27 2,140.07 -1,979.63 2,235,652.76 207,922.53 2.00 2,915.27 5,300.00 16.17 317.23 4,202.31 4,057.81 2,161.73 -1,999.67 2,235,674.90 207,903.01 2.00 2,944.79 5,400.00 14.17 317.23 4,298.82 4,154.32 2,180.94 -2,017.44 2,235,694.53 207,885.71 2.00 2,970.95 5,500.00 12.17 317.23 4,396.19 4,251.69 2,197.66 -2,032.90 2,235,711.62 207,870.65 2.00 2,993.73 5,600.00 10.17 317.23 4,494.29 4,349.79 2,211.88 -2,046.06 2,235,726.15 207,857.85 2.00 3,013.10 5,700.00 8.17 317.23 4,593.01 4,448.51 2,223.57 -2,056.87 2,235,738.10 207,847.31 2.00 3,029.03 5,800.00 6.17 317.23 4,692.22 4,547.72 2,232.73 -2,065.35 2,235,747.46 207,839.06 2.00 3,041.50 5,900.00 4.17 317.23 4,791.81 4,647.31 2,239.34 -2,071.46 2,235,754.22 207,833.11 2.00 3,050.51 6,000.00 2.17 317.23 4,891.65 4,747.15 2,243.40 -2,075.21 2,235,758.36 207,829.46 2.00 3,056.04 6,100.00 0.17 317.23 4,991.63 4,847.13 2,244.90 -2,076.60 2,235,759.89 207,828.11 2.00 3,058.07 6,108.37 0.00 317.23 5,000.00 4,855.50 2,244.90 -2,076.60 2,235,759.90 207,828.10 2.00 3,058.08 End Dir :6108.37'MD,5000'TVD 6,200.00 0.00 0.00 5,091.63 4,947.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 6,300.00 0.00 0.00 5,191.63 5,047.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 6,400.00 0.00 0.00 5,291.63 5,147.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 6,500.00 0.00 0.00 5,391.63 5,247.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 6,600.00 0.00 0.00 5,491.63 5,347.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 6,700.00 0.00 0.00 5,591.63 5,447.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 6,800.00 0.00 0.00 5,691.63 5,547.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 6,900.00 0.00 0.00 5,791.63 5,647.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,000.00 0.00 0.00 5,891.63 5,747.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 10/20/2016 2:28:31PM Page 4 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTDN Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company ND Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +EI•W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 5,847.13 7,100.00 0.00 0.00 5,991.63 5,847.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,200.00 0.00 0.00 6,091.63 5,947.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,300.00 0.00 0.00 6,191.63 6,047.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,400.00 0.00 0.00 6,291.63 6,147.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,500.00 0.00 0.00 6,391.63 6,247.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,501.87 0.00 0.00 6,393.50 6,249.00 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 Tyonek 65 7,502.87 0.00 0.00 6,394.50 6,250.00 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,600.00 0.00 0.00 6,491.63 6,347.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,700.00 0.00 0.00 6,591.63 6,447.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,800.00 0.00 0.00 6,691.63 6,547.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,800.87 0.00 0.00 6,692.50 6,548.00 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 Tyonek 83 7,900.00 0.00 0.00 6,791.63 6,647.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 7,976.87 0.00 0.00 6,868.50 6,724.00 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 Tyonek 90 8,000.00 0.00 0.00 6,891.63 6,747.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 8,100.00 0.00 0.00 6,991.63 6,847.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 8,200.00 0.00 0.00 7,091.63 6,947.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 8,274.87 0.00 0.00 7,166.50 7,022.00 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 Tyonek 110 8,300.00 0.00 0.00 7,191.63 7,047.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 8,400.00 0.00 0.00 7,291.63 7,147.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 8,500.00 0.00 0.00 7,391.63 7,247.13 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 8,545.87 0.00 0.00 7,437.50 7,293.00 2,244.90 -2,076.60 2,235,759.90 207,828.10 0.00 3,058.08 Tyonek 140 8,600.00 • 0.00 0.00 7,491.63 .7,347.13 2,244.90 -2,076.60 2,235,759.90 • 207,828.10• 0.00 3,058.08 Total Depth:8600'MD,7491.63'TVD-41/2" Targets Target Name •hit/miss target Dip Angle Dip Dir. ND +N/•S +El-W Northing Easting -Shape (') (') (usft) (usft) (usft) (usft) (usft) K-1 wp01 T65 Tgt2 0.00 0.00 6,394.50 2,244.90 -2,076.60 2,235,759.90 207,828.10 -plan hits target center -Circle(radius 50.00) K-1 wp01 T83 Tgt3 0.00 0.00 6,694.50 2,245.00 -2,076.61 2,235,760.00 207,828.10 -plan misses target center by 0.10usft at 7802.87usft MD(6694.50 TVD,2244.90 N,-2076.60 E) -Circle(radius 50.00) K-1 wp01 T90 Tgt4 0.00 0.00 6,869.50 2,244.90 -2,076.60 2,235,759.90 207,828.10 -plan hits target center -Circle(radius 50.00) K-1 wp01 T3 Tgt1 0.00 0.00 3,769.50 1,455.50 -2,295.58 2,234,976.00 207,590.20 -plan misses target center by 710.22usft at 4766.60usft MD(3706.75 TVD,2018.42 N,-1867.10 E) -Circle(radius 50.00) 10/20/2016 2:28:31PM Page 5 COMPASS 5000.1 Build 81 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Kalotsa 1 Company: Hilcorp Energy Company ND Reference: Kalotsa 1 wp04 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 1 wp04 @ 144.50usft Site: Kalotsa North Reference: True Well: Kalotsa 1 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 1 Design: Kalotsa 1 wp04 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 1,500.00 1,349.29 7 5/8" 7-5/8 9-7/8 8,600.00 7,491.63 4 1/2" 4-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (0) 4,357.98 3,356.50 Beluga 120 8,274.87 7,166.50 Tyonek 110 8,545.87 7,437.50 Tyonek 140 4,665.66 3,617.50 Tyonek TX 5,146.93 4,056.50 Tyonek T6 4,853.09 3,784.50 Tyonek T3 4,568.83 3,533.50 Beluga 135 7,800.87 6,692.50 Tyonek 83 7,501.87 6,393.50 Tyonek 65 7,976.87 6,868.50 Tyonek 90 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 250.00 250.00 0.00 0.00 Start Dir 4°/100':250'MD,250'TVD 1,411.72 1,288.49 327.28 -302.75 End Dir :1411.72'MD,1288.49'TVD 3,784.93 2,923.03 1,590.34 -1,471.11 Start Dir 2°/100':3784.93'MD,2923.02'TVD 6,108.37 5,000.00 2,244.90 -2,076.60 End Dir :6108.37'MD,5000'ND 8,600.00 7,491.63 2,244.90 -2,076.60 Total Depth:8600'MD,7491.63'TVD 10/20/2016 2:28:31PM Page 6 COMPASS 5000.1 Build 81 s i Hilcorp Energy Company Ninilchik Unit 0 1 Kalotsa Kalotsa 1 Kalotsa 1 `' Kalotsa 1 wpO4 'Li 1 ' Sperry Drilling Services Clearance Summary Anticollision Report 20 October,2016 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) 't Reference Design: Kalotsa-Kalotsa 1-Kalotsa 1-Kalotsa 1 wp04 Well Coordinates:2,233,465.69 N,209,850.08 E(60°06'14.78"N,151°35'24.38"W) Datum Height: Kalotsa 1 wp04 @ 144.50usft Scan Range: 0.00 to 8,600.00 usft.Measured Depth. Scan Radius is 1,058.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 81 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 Milt . 111111 HALLIBURTON Sperry Drilling Services 0 • Hilcorp Energy Company HALLI B U RTO N Ninilchik Unit Anticollision Report for Kalotsa 1 -Kalotsa 1 wp04 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Kalotsa-Kalotsa 1-Kalotsa 1-Kalotsa 1 wp04 Scan Range:0.00 to 8,600.00 usft.Measured Depth. Scan Radius is 1,058.20 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kalotsa Kalotsa 2-Kalotsa 2-Kalotsa 2 wp03 484.18 25.60 484.18 23.06 462.64 10.071 Ellipse Separation Pass- Kalotsa 2-Kalotsa 2-Kalotsa 2 wp03 525.00 26.60 525.00 23.84 502.81 9.627 Clearance Factor Pass- Kalotsa 3-Kalotsa 3-Kalotsa 3 wp04 447.78 61.53 447.78 59.19 423.19 26.229 Centre Distance Pass- Kalotsa 3-Kalotsa 3-Katotsa 3 wp04 450.00 61.53 450.00 59.18 425.32 26.107 Ellipse Separation Pass- Kalotsa 3-Kalotsa 3-Katotsa 3 wp04 3,775.00 984.52 3,775.00 906.96 3,603.89 12.693 Clearance Factor Pass- Kalotsa 4-Kalotsa 4-Katotsa 4 wp04 861.03 15.82 861.03 11.32 832.08 3.512 Ellipse Separation Pass- Kalotsa 4-Kalotsa 4-Kalotsa 4 wp04 875.00 16.40 875.00 11.66 845.22 3.462 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.00 8,600.00 Kalotsa 1 wp04 MWD+SC+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 20 October,2016- 15:57 Page 2 of 4 COMPASS • • Hilcorp Energy Company HALLIBURTON Ninilchik Unit Anticollision Report for Kalotsa 1 -Kalotsa 1 wp04 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Kalotsa 1 wp04 @ 144.50usft. Northing and Easting are relative to Kalotsa 1 Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00",Grid Convergence at Surface is:-1.38". Ladder Plot 111I I I C I I TEM -I I 1 901 I I 1 I I I I O I I I Ei 1 O 1 I I CO ---- i---- VI 1 I I % I I LEGEND `4 601 a1 I o - t I Q 1 I 0) I I - - Kalotsa 2,Kabba2,Kalotsa 2wp03V0 U) 1 I L A - --_L---- ---_L---- --;---- ----J---- _---J_-- --�-- Kalo5a3,Kabtsa3,Kalotsa 3wp04V0 ` I I I I Kalotsa 4,Kabtsa4,Kalolsa4vvp04V0 I 1 1 I -$ Kalotsa 1 wp04 0) I I 1 I o 30, 1 �� 1 I 1 I ° 1 I I 1 1 I I _ I Air _, I JI 1 IL CD Ui ==� I I I I 0 0 700 1400 2100 2800 3500 Measured Depth(700 usft/in) 20 October,2016- 15:57 Page 3 of 4 COMPASS • • Hilcorp Energy Company HALLIBURTON Niniichik Unit Anticollision Report for Kalotsa 1 -Kalotsa 1 wp04 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor V10.00— 6.75 7.50 6.25 - LEGEND U - l9 - c 5.00 $ Kalotsa 2,Kalotsa 2,Kalotsa 2wpO3 V0 -6- Kalotsa 3,Kabt;a3,Kalotsa 3wp04V0 o. _ Kalotsa 4,Kalotsa 4,Kalotsa 4 wp04 VO to 3.75 $ Kabtsa 1 wp04 2.50 -- - Collision Avoidance Req —No-Go Zone-Stop Drilling 1.25 0.00 1111 ' 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1 0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 MeasuEd Depth(6E0 usftfr1) 20 October,2016- 15:57 Page 4 of 4 COMPASS Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Wednesday, November 16, 2016 9:34 AM To: mmyers@hilcorp.com Cc: Davies, Stephen F (DOA) (steve.davies@alaska.gov) Subject: Kalotsa 1 (PTD 216-132) Monty, A couple of items I saw on the PTD: 1) Diverter waiver will not be granted. First well on pad and control points in area are too far away. Please provide a diverter layout for pad. 2) Surface cement volume calculations are somewhat off due to overlapping depths(lead/tail). Too much lead cement... please recalculate volumes. 3) What is the cement type and yield for the 4.5" liner? 4) Kick tolerance for the 6%" hole section is very tight. What are you going to mitigate risk in this hole section? 5) Not likely any issues but the Anti-collision data does not mention the other wells in area from Susan Dionne and Paxton pads that are close. Collision Report only input the proposed wells on the Kalotsa pad. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 • • Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Wednesday, October 26, 2016 7:05 AM To: Davies, Stephen F (DOA) Subject: RE: Kalsota 1 (PTD#216-132) - Permit to Drill Application Questions Good morning Steve.Thank you for the questions, please see the responses in red below. 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: Tuesday, October 25, 2016 5:05 PM To: Monty Myers Subject: Kalsota 1 (PTD #216-132) - Permit to Drill Application Questions Monty, In the Anticipated Drilling Hazards section for the 6-3/4" hole section, I notice that Hilcorp states: "No abnormal temperatures are present in this section." Pressure is not mentioned as it is for the 9-7/8" hole section. I assume that this is just a cut-and-paste omission since the geo-prognosis suggests that the gradient for the well is uniformly about 8.7 ppg EMW. Correct?You are correct. We anticipate this to be a normally pressured area, and is a development well, however to be conservative since it is the first well on the pad, we assume a few tenths above normal gradient for the well. I'm not aware of H2S within the Ninilchik Unit area. Has Hilcorp encountered any H2S during operations there? To my knowledge Hilcorp hasn't encountered any H2S in this area. Since this is the first well from a new drilling pad, the AOGCC requires cuttings samples, a mud log, and a well logging suite consisting (at a minimum) of gamma ray, resistivity, and porosity curves recorded from base of conductor pipe to the total depth of the well. We will accommodate your request for these, as we will be taking samples and logging also. Thanks for your help. 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. 1 1 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: "/ Or (5 D 14 ( PTD: 216 r ( 3 Z-- /Development Service Exploratory Stratigraphic Test Non-Conventional — FIELD: /V/1/4 / ( ti/ Gam' POOL: Ig _-t._ _d--A-(2_Z-- g 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'sample 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: keds,:,-(4L.. / czry('j 6- c-� �c'' ± tvPI( 77 Well Logging c cr i((_e I t-Tca t e"-Z-- t,Le- 1. ce l d 1(G-it5' (� 74-6_, )CC Requirements L J fe--5 Lvtk1 � 141-a,--1 / )+J 4 IAA-tc,�.c7 vtz �' zs �e. i C_13-11 d Per Statute A 1.0 .0� d 2 B and�Re lation 25. 1, composite curves for well logs run must be submitted to the AOGCC A.5 within 90 days after completion, suspension or abandonment of this well. ' /D,2%/,6 Revised 2/2015 f • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: _ /(2,, Ct, / ( e_tre_c-e,d) PTD: Z-T6, — l tl l.-- /Development _Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: Ai/EV/i l e CLC lL POOL: f /" 4 A'// 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'sample 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 foilpw'ng w l to are / also` required for this well: c� _�a-,� l r5I Zt. l( V Well Logging i l( r--7^01/1-1.- tt- it P > djr`./l�-� • •� �-ei n / / gg g /b/cz�� k Requirements "/k e- 6". _- reek �e-r y-may � ./2� L'e �// .-1-t. ze..›Y--e-,,s, Per ati.ite AS 31.0503( (d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCCC ' within 90 days after completion, suspension or abandonment of this well. // 'fin. �� Revised 2/2015 • • ❑❑ o w.v a a Nas tT a y O 4 a O07 C O Y �, .y W V1 M. O L7 ani U N 3' N' O J. N Of C7, . o, a C0 O O. , _ c ' 'C' ' , 0) , , , , o, , ' j m E , 3 a, , ac), 04 0, V Y ' o, Eu_ 0 0, , , , , , , E 8, , _ of , , , ai. > 0 CL W. O. m C. . .0 Co 0 o a a , O E c,) -• v —, a as . r a O N • � 0' o f -OV y 6 4 Cl) C . 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Kalotsa 1 50-133-20657-00-00 Ninilchik Field Kenai Peninsula Borough, Alaska December 16, 2016 – December 29, 2016 Provided by: Approved by: Jacob Dunston Compiled by: Ralph Winkelman Russell Wardner Distribution Date: January 31, 2017 Hilcorp Alaska, LLC Kolatsa 1 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 2 1.1 Equipment Summary ...................................................................................................................... 2 1.2 Crew................................................................................................................................................ 2 2 GENERAL WELL DETAILS ................................................................................................................... 3 2.1 Well Objectives ............................................................................................................................... 3 2.2 Hole Data ........................................................................................................................................ 4 2.3 Daily Activity Summary ................................................................................................................... 5 3 GEOLOGICAL DATA ............................................................................................................................. 7 3.1 Lithostratigraphy ............................................................................................................................. 7 3.2 Lithology Details ............................................................................................................................. 8 3.3 Sampling Program ........................................................................................................................ 25 4 DRILLING DATA .................................................................................................................................. 26 4.1 Surveys ......................................................................................................................................... 26 4.2 Bit Record ..................................................................................................................................... 30 4.3 Mud Record .................................................................................................................................. 31 4.4. Drilling Progress ........................................................................................................................... 32 5 DAILY REPORTS ................................................................................................................................ 33 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 Hilcorp Alaska, LLC Kolatsa 1 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computers – Surface Logging (3) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 Ditch gas QGM gas trap; Flame ionization total gas & chromatography. Hook Load / Weight on bit WITS from Pason 0 Mud Flow In Calculated value derived from Strokes/Minute and Pump Output 0 Mud Flow Out WITS from Pason 0 Pit Volumes, Pit Gain/Loss WITS from Pason 0 Pump Pressure WITS from Pason 0 Pump Stroke Counters (2) WITS from Pason 0 Rate of Penetration Calculated from Pason 0 RPM WITS from Pason 0 Torque WITS from Pason 0 WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML038 Logging Geologists Years1 Days2 Sample Catchers/Loggers Years Days2 Russell Wardner 17 Mike Skiles 8 14 Ralph Winkelman 26 19 Donna New 10 9 Ashley Wilderom 4 5 *1 Years’ experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. Hilcorp Alaska, LLC Kolatsa 1 3 2 GENERAL WELL DETAILS 2.1 Well Objectives Kalotsa #1 is and 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 268’ MD. Maximum hole angle will be 46 deg. and TD of the well will be 8600’ MD/ 7492’ TVD, ending with 0 deg inclination left in the hole. The vertical section will be 3058’. Operator: HILCORP ALASKA, LLC Well Name: Kalotsa 1 Field: Ninilchik Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Rance Pederson, Robert Wall , Clint Montague, Adam Dorr Location: Surface Coordinates 2200’ FSL, 446’ FWL, Sec 7, T1N, R13W, SM, AK Ground ( Pad ) Elevation 126.5’ AMSL Rotary Table Elevation 18’ KB – 144.5’ AMSL Classification: Development – Gas API #: 50-133-20657-00-00 Permit #: 216-132 Rig Name/Type: Saxon 169 / Land / Double Spud Date December 16, 2016 Total Depth Date: December 29, 2016 Total Depth 8866.00’ MD/ 7772.90’ TVD Primary Targets Tyonek 65 7501’MD/ 6394’TVD, Tyonek 83 7800’MD/ 6693’TVD, Tyonek 90 7976’MD/ 6869’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 Hilcorp Alaska, LLC Kolatsa 1 4 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth LOT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 9 7/8” 1518’ 1366.3’ Beluga 9.2 46.17 7 5/8 1509’ 1360.2’ 14.3 6 ¾” 8866’ 7772.9’ Tyonek 9.3 1.69 4 ½” 8846’ 7752.8 Hilcorp Alaska, LLC Kolatsa 1 5 2.3 Daily Activity Summary December 14, 2016: Rig up mudlogging unit December 15, 2016: Continue rig up. Prepare to spud well. December 16, 2016: p/u drill pipe/racked back tagged bottom at 112’, total drill pipe racked back 35 stands, gather strap 9 joints of HWDP, p/u HWDP, rack back 4 stands, gather directional BHA, install MWD sensors, gather/size 6.5” dc slips, collar clamp, pump through top drive, fill conductor, close manual IBOP, pressure test surface lines, leak between pumps, tighten union, retest 500 psi low back Kelly hose, p/u directional subs and bit, trouble shoot Pason, p/u and m/u BHA, drill 112’-245’, circulate hole clean, pooh f/245’ to bit, m/u BHA, down load, load sources, m/u BHA to 245’, drill 245’-291’, KOP 245’, rack back 1 stand HWDP, p/u jars/single HWDP, drill 291’-555’. December 17, 2016: drill 555-791, wipe new hole, drill 791 to 1518, pump high vis sweep 20% increase cuttings , wipe hole, pooh 1518 to 170, madpass every slide, monitor well, blow back kelly hose/standpipe, hole fill calculated 10.18 bbls, meas. 30 bbl diff. 19+.82 bbls over, rig service, grease/inspect crown blocks, TD, DW, Brake linkage/drive line, check all pins, keepers, change TD motor POP board, Trip in hole from 170' at report time. December 18, 2016: : Run in hole to bottom, circulate bottoms up, pooh, lay down BHA and bit, download memory, pull wear bushing, dummy hangar joint, clean rig floor, rig up casing equip, run 7.625 casing, land out at 1509.33’ 200 gpm press = 57, circulate while r/u cement equip/crew, shut down pumps, break off top drive, circulate swedge, blow back kelly hose, r/u cement bowl headlines and manifold, pjsm with SLB cement crew, circulate on casing while batching in cement, shut down rig pump, line up cementers, pump 5 bbl water, pressure test lines 1600/3800, line up manifold, pump 23 bbls 10 ppg mudpush at 5 bpm, drop bottom plug SLB pump 89.6 bbl 12 ppg lead at 4.8 bpm, 27.4 bbl 15.4 ppg tail, drop top plug, displace 67 bbl, 9.2 ppg mud at 4.8 bpm, fcp 500 psi, bumped plug 500 psi over at 2215 hrs, held 3 min, bled back 0.5 bbl, floats held, wash up/blow back cement lines, blowback standpipe/displacement feed lines rig down cementers, suck out cellar, casing bails, drill string, SLB left at 24 hrs, back out landing joint, wash out top of casing hanger, make up packer to landing joint, set packer December 19, 2016: back out landing joint, wash out top of casing hanger, make up packer to landing joint, set packer , tighten all lock downs, back out of packer, lay down running tool and landing joint, nipple down diverter, clean cellar, nipple up well head, pressure test low 500 high 1500 for 15 min, stage bop cradle, set crane, install spacer spool, fly in bops, change studs on bottom of stack, move cradle load out diverter equipment, install inside kill inside choke, hydraulic choke and kill, continue nipping up. December 20, 2016: Nipple up bop, test bop, test 7 5/8" casing to 3500 for 30 min, install 9" wear bushing, repair bell nipple and install, strap and pickup drill pipe December 21, 2016: continue pick up drill pipe for 115 total stands in derrick, stage, strap and tally BHA, make up BHA to 120, worm up tools down load, pulse test, s/m radioactive sources ins sources, continue RIH with BHA, single in hole 590-1117, circulate bottoms up, single in 1117-1356, from derrick to 1403, tag cement, drill out float collar at 1422 and shoe at 1507, clean out to 1518, drill to 1538, circul ate bottoms up, pull back into casing and perform a fit test to 14.3 ppg EMW with 9.2 ppg mud, applied pressure , pre-job safety meeting for displacement, displace well with KCL mud, clean shaker tank, change shaker screes to 140 mesh, transfer mud into active. December 22, 2016: drill 1538-2482, circulate bottoms up, pump 20 bbl high vis sweep, wipe hole to shoe, no issues, hole took 1.8 over calculated fill, service rig, grease drawworks blocks, crown, check brakes, I.R. check bear traps, rih 1487-2482, drill 2482-2984. Hilcorp Alaska, LLC Kolatsa 1 6 December 23, 2016: drill 2984-3481; pump sweep circulate 20 bbls high vis 20% increase cuttings, pooh 3481-2552, tight spots at 2819-2809 25k, 2764-2760 25k, 2708-2678 25km 2579 30k, on elevators 2552- 2390, rig service, grease drawworks, check brakes, grease top drive, reset c.o.m., rih 2390- 3481, no issues, drill 3481-3851, pump 20 bbl high vis sweep, drill 3851-4228. December 24, 2016: drill 4228-4476, pump sweep, circulate hole clean, wipe/pooh on elevators, 4476- 3416, tight 3763 and 3653 30k over, work thru once, hole fill 1.8 bbls over theoretical, rih 3416-4476 no issues, drill 4476-5284 December 25, 2016: drill 5281-5470, pump sweep, circulate hole clean, wipe hole, wipe 5470-4786, 30k over at 4815, multiple tight spots 4815-4670, ream tight spots 4622-4507 and 3311-2346, pump high vis sweep, wipe 2346-1490 on elevators, grease drawworks, top drive, blocks and I.R., rih 1496-5348, no issues, hole took 2.3 bbl under calculated displacement, ream last stand, level derrick, tagged fill at 5461, drill 5470-5718 December 26, 2016: drill 5718-6466, pump sweep, wipe 6466-5441, drill 6466-6854 December 27, 2016: drill 6854-6970, work on top drive, drill 6970-7027, circulate bottoms up, pump hi vis sweep, pull to 6900, circulate at 48 spm, 753u max, work on top drive, rih to bottom, 20u wiper gas, drill 7027-7463, circulate bottoms up, pump high vis sweep, wipe to 6464, wiper gas 3268u, drill 7463- 7527 December 28, 2016: drill 7527-8334, replace top drive hose, drill 8334-8347, rack back stand and repair top drive, drill 8347-8619 December 29, 2016: drill 8619-8866, pump sweep, circulate hole clean, wipe to shoe, (spot ream tight spots 30-40k over @7638, 5395, 5331 and 5020, back ream 4900-4300, 267u max, pump hi vis sweep, circulate hole clean, 20u max pooh 4300-1494,) service rig, rih 1494-5200 December 30, 2016: rih, circulate bottoms up at 6469’, max gas 2014u, rih, 8361, tight pull to 8214, circulate bottoms up, max gas 1916u, rih 8214-83500, wash ream 8350-8450, rih 8450-8866, pump sweep, circulate weight up to 9.5 ppg, max gas 286u, pooh to 8048 l/d drill pipe, condition mud and circulate, max gas 44u, rih 8048-8432, pooh l/d dp to 1110 December 31, 2016: l/d drill pipe, and BHA, break and l/d bit, pulled wear ring and dummy ran hanger, r/u W eathorford casing equip, rih w/4 1/2" casing, circulate bottoms up @ shoe, 3790 and 6428 with max gases 1u, 28u and 104u, rih casing from 6665. January 1, 2017: Continue running casing. Land at 8846’. Circulate and condition mud. Rig up cementers. Pump mud push too soon. Circulate out and build new push. Cement as per plan. Rig down logging unit. Hilcorp Alaska, LLC Kolatsa 1 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geologist, Jacob Dunston: FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Tyonek T6 5144.9 4057 -3912 5,137 4,063 -3,918 Tyonek65 7501.1 6394 -6249 7,530 6,438 -6293 Tyonek83 7800.1 6693 -6548 7,842 6,749 -6,604 Tyonek90 7976.1 6869 -6724 8,004 6,911 -6,766 Tyonek110 8274.1 7167 -7022 8,301 7,208 -7,063 Tyonek140 8545.1 7438 -7293 8,552 7,459 -7,314 Hilcorp Alaska, LLC Kolatsa 1 8 3.2 Lithology 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 spud at 134’MD. 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 form ing 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. Sand/ Conglomerate (134'-210') = medium to medium dark gray overall with abundant lithics dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass, light green to yellowish green, trace orange, dusky red, rust and pale rose; very fine upper to 12mm pebbles, dominantly medium lower to coarse upper; angular to trace subrounded, dominantly subangular; poorly sorted; unconsolidated with trace clay supporting matrix; non calcareous. Sand/ Conglomeratic Sand (210' - 240') = medium gray overall with abundant multicolored liths; fine lower to very coarse upper, dominantly medium to coarse; angular to subangular; poorly sorted; unconsolidated; non calcareous. Sand/ Conglomeratic Sand (240'-300') = medium gray overall with scattered black, red, light brown to yellow; poor to moderately well sorted; lower very coarse to upper fine; dominantly lower coarse to lower medium; subrounded to angular; dominantly subangular to angular; moderate to low sphericity dominant, occasionally high; 30-40% lithics, dominantly quartz, common plagioclase; unconsolidated with some pasty white interstitial clay; non calcareous. Clay (330') = medium gray, trace patchy yellow gray; smooth, pasty; low cohesion; moderate adhesion; very slightly expansive; non calcareous; evident matrix of increasingly pebble conglomerate with dominant angular clasts with low sphericity; 10-15% mix of plutonic, sedimentary and coal lithics; sand fines overall with lower fine to upper medium dominant with scattered very coarse to granule. Sand/ Conglomeratic Sand (330'-420') = medium gray with common black, yellow, red to blue lithics; initially very poorly sorted, lithic conglomerate includes common very coarse to coarse angular coal clasts common with yellow matrix support, and contorted bedding; becomes poorly sorted, decrease coal clasts upper very coarse to upper fine with dominantly lower medium to coarse upper; very angular to subrounded; dominantly subangular to angular; low to moderate sphericity dominant; trace gray white moderate soluble ash matrix, unconsolidated ,trace grain to grain contacts; initial coaly sample contains 30% max lithics, includes trace well round greenstone; persistent dark lithics throughout, with dominant quartz, common plagioclase; non calcareous. Hilcorp Alaska, LLC Kolatsa 1 9 Sand/ Conglomeratic Sand (420'-480') = medium gray with black, dark gray, brown, yellow to green; poor to very poorly sorted; granule to upper fine; very coarse to coarse common, dominantly medium lower to upper coarse; angular to subrounded; moderate to low sphericity dominant; impacted, grind to polish abrasion; dom inant quartz, 20% lithics, common plagioclase; unconsolidated with minor soluble clay matrix; non calcareous. Conglomeratic Sand/ Sand/ Mudstone (480'-540') = thick pasty medium to olive gray clays associated with influx pebbly conglomeratic sand, clays poor cohesive, slick to poorly soluble; sands mix poor sorted very coarse to fine with dominant medium to coarse, scattered pebbles; some firm friable fine grain supported massive sandstone; becomes fairly well sorted sand by 540' with dominantly lower fine to lower coarse with scattered upper coarse to upper very coarse; dominantly quartz, common plagioclase, 15% lithics; mudstone habits common large nodular to clumpy, occasionally elongated cuttings, smooth lack pdc textures; sandstone commonly contains floating random orient coal clasts; non calcareous. Coal (540'-570') = dark brown, black to very dark gray; moderate hard to firm; irregular gritty to smooth texture; irregular black to brown wavy thin discontinuous coal needles common <1mm thick, stacked in pinched-curved contacts lesser smooth fractured cuttings; brittle to slight tough, dense; thin dirty shaley beds; no visible out gassing or sample fluorescence. Sand/ Conglomeratic Sand (570'-630') = medium to medium light gray; initially poor sorted with common medium to very coarse coal clasts becomes fair sorting, marked decrease o/a lithics to 10% with dominant quartz, common plagioclase and very fine to coarse lower with dominant upper medium to upper fine; fining sands angular to subround, dominantly subangular; increase moderate to hi sphericity, common polish-etch; pasty clay continued olive gray hue possible thin claystone beds associated with thin fine grain supported, easy friable sandstone beds; non calcareous; scattered 20-30 mm pebbles. Sand (630'-690') = medium gray, black, dark gray green, red, pink, yellow; lithic rich moderate well to fair sorted unconsolidated sand with trace easy friable sandstone cuttings, grading to sandy siltstone; upper coarse to fine lower; dominant fine upper to upper medium; subrounded to angular; dominantly subrounded to subangular; moderate to hi sphericity; polish, etch to frost abrasion; trace crenulated chlorite micas; dominant quartz, common plagioclase, 20% lithics; unconsolidated and loose, minor clay support. Sandstone (690'-790') = medium to medium light gray; easy friable; grain supported; angular to subrounded; moderately well sorted; fine to coarse, dominantly fine to medium; dominant point to point contact fabric to fines in part to silty s andstone with notable floating coal macerals; dom inant quartz, common plagioclase, 10-20% lithics; marked overall fining in lithics, common subrounded Claystone (790'-840') = olive brown; moderate firm to friable dominant, 10% pasty smooth moderate reactive, smooth with elongated pdc marks hydrating to clay; moderate silty to slight gritty texture; low opacity, dull to earthy; irregular open earthy fracture; non calcareous; trace sandy fabrics with very fine oblate black pellets; grades to siltstone, influx of sands upper fine to medium upper dominant by 840' with pale greenish white colloidal ashy clays; no sample fluorescence. Sand/ Conglomeratic Sand (840'-900') = lithic rich dominant black, dark gray, green very poor to poor sorted sands, fining down; fine to upper coarse with dominant coarse to medium fining to dominant medium to fine; angular to subrounded; dominant subangular; low to moderate sphericity; dominant quartz, common plagioclase, 10-20% lithics, impacted subrounded, sharp breaks common; unconsolidated with some soluble clay; non calcareous. Hilcorp Alaska, LLC Kolatsa 1 10 Sand/ Conglomeratic Sand (900'-960') = medium to medium dark gray; continued lithic rich 20-10% black, dark gray, green, yellow to red; poor sorting; fine to very coarse; dominantly coarse to medium; angular to subrounded; dominantly subangular to angular; low to moderate sphericity; dominant quartz, common plagioclase, lithics decrease with slight overall fining; common impacted frosted texture, etched to pitted ; good to moderate polish vitreous quartz,, lithics unconsolidated with continued minor trace amounts slightly colloidal clay matrix; non calcareous; trace mineral fluorescence. Conglomeratic Sand (960'-990') = medium to dark gray; poor sorted; very coarse to fine; dominant very coarse to coarse; angular to subrounded; dominant subangular; low to moderate sphericity; 40% dark lithics; trace medium light gray siltstone. Sand (990'-1020') = medium light gray; very well sorted; very fine to medium; dominant very fine to fine; angular to subrounded; dominantly subrounded; pasty easy soluble gray white ashy clay; marked decrease to 5% black lithics; dominant quartz; unconsolidated clay matrix; non calcareous. Sand (1020'-1050') = medium gray; 15% dark gray to black lithics; very slight coarsening to very fine to coarse with dominant upper fine to medium upper; subrounded to angular; dominantly subrounded; high to moderate sphericity; continued pasty soluble clay support; non calcareous. Coal/ Carbonaceous Shale (1050'-1080') = dark brown, pitch black to moderate brown hue on gritty shaley breaks; moderate hard to hard; slightly tough, blocky to irregular splintery fracture. Sand (1080' - 1140') = medium to medium light gray overall with individual liths dominantly light to dark gray, clear to translucent quartz and volcanic glass, trace light to medium greenish gray and rare pale rose; fine lower to trace very coarse lower, dominantly fine upper to medium lower; angular to subangular; moderately well sorted; unconsolidated. Tuffaceous Claystone (1140' - 1200') = medium light to light gray with very light brownish gray secondary hues; very soft; very sticky; shapeless, globular cuttings; very soluble; hydrophilic; moderately expansive; very poor cohesiveness; very good adhesiveness; non calcareous; trace thin coal beds throughout interval. Coal (1200' - 1230') = black with grayish black secondary hues; hard; blocky to planar fracture; massive to platy and flaky; trace conchoidal and birdeye fracture; earthy to resinous luster; smooth to slightly silty texture; no outgassing observed. Sand (1230' - 1290') = medium light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light gray, light to medium greenish gray and black; very fine upper to medium upper, dominantly fine; angular to subangular; moderately well sorted; unconsolidated; non calcareous; trace to common thin coals throughout interval. Tuffaceous Claystone (1290' - 1340') = medium light to light gray with very light brownish gray secondary hues; very soft; very sticky; shapeless, globular cuttings; very soluble; hydrophilic; moderately expansive; very poor cohesiveness; very good adhesiveness; non calcareous; trace thin coal beds throughout interval; trace black microthin carbonaceous laminations and inclusions in trace firm fragments. Sand (1340' - 1410') = medium gray overall with a salt and pepper appearance, individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black and trace medium greenish gray; very fine lower to very coarse upper, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poorly sorted; unconsolidated; non calcareous; continued thin coal beds throughout interval. Hilcorp Alaska, LLC Kolatsa 1 11 Tuffaceous Claystone (1410' - 1470') = medium light to light gray with light brown to light brownish gray secondary hues; very soft; very sticky; shapeless, amorphous cuttings; silty to clayey texture; dull to greasy luster; very soluble; moderately expansive; hydrophilic; poor cohesiveness; fair to good adhesiveness; non calcareous; continued trace thin coals throughout interval. Sand/ Sandstone ( 1470' - 1518') = medium to medium dark gray with a moderate to strong salt and pepper appearance; very firm to moderately hard; fine lower to trace very coarse upper, dominantly medium; angular to subangular; poor to fair sorting; moderately consolidated with a calcareous matrix. Conglomeratic Sandstone (1518'-1550') = medium dark gray; poor to fair sorted; very fine to coarse upper, few granules; angular to subround; moderate to high sphericity; 50% lithic arenite with moderate to good porosity; grain supported crunchy hard to unconsolidated; weak calcareous; meta sedimentary lithics. Coal/ Carbonaceous Material (1550'-1650') = black, brownish gray with black micro-laminae; low grade subbituminous with thin flaky to rare blocky cuttings habit dull to resinous, rare vitreous luster; disseminated fine specks in tuffaceous mudstones common with associated increase si lt sparkle; no outgassing. Tuffaceous Claystone/ Sand (1650'-1700') = medium light gray with bluish gray hue; colloidal, hydrated smooth texture with silt sparkle common; unconsolidated medium dark gray lithic ar enite sands poor sorted very fine to very coarse; angular to subround; lithics dark gray meta sedimentary, common high sphericity; quartz varied overgrowth, frost, disaggregated by 1695' of hard grain supported sandstone fining to fine to medium dominant; good effervescence to HCl, yellow rinds of cement and on grain edges; no sample fluorescence. Tuffaceous Claystone (1700'-1760') = medium to medium light gray with bluish gray hue; smooth, silty to clayey texture; reactive, expansive; poor soluble; good cohesion; pasty, slight adhesion; detrital silt sparkle; tabular, nodular to curved cuttings; open earthy fracture; low density; disseminated carbonaceous mater common; non calcareous. Sandstone (1760'-1785') = medium dark gray; poor sorted; very fine to coarse; subround to very angular; moderate to high sphericity dominant; disaggregated, to hard grain support, calcite cement; lithic arenite; 50% meta sedimentary, lithics; quartz common with good solution frost, etched, polished to grind, trace brown to orange tint mica sheets; good porosity. Coal (1830'-1860') = black to dark brown gray; moderate hard to hard; dense blocky to subhackly cuttings rare subconchoidal fracture; resinous to subvitreous; planar to irregular bedding varied brittle to slight tough; smooth texture; disseminated carbonaceous mater, coal macerals in interbed ded tuffaceous claystone; trace fine. Tuffaceous Siltstone/ Sand (1870'-1910') = blue gray; firm friable, slight dense silt support; elongate to platy, sub-blocky; more resistant to hydration than claystone; sand well sorted very fine to fine lithic arenite. Coal (1910'-1930') = black with brownish gray hue; firm to moderate hard; irregular subplaty, slight mottled thin bed structure, light brown argillaceous partings, plant material; pinpoint outgassing observed. Sand/ Coal (1930'-1980') = light gray quartz rich sand, very well sorted; very fine to fine; subangular to subround; high sphericity; unconsolidated; clayey matrix support; thin blocky black coal seam with white crystalline aggregates on bedding/fracture planes. Hilcorp Alaska, LLC Kolatsa 1 12 Tuffaceous Claystone (1980'-2040') = medium light gray with bluish gray hue; soft, pasty to mushy; reactive colloidal smooth to silty; moderate expansive; low cohesion; poor adhesion; massive bedding structure; open earthy fracture; low density; organic poor; increase detrital carbonaceous mater, thin carbonaceous shale, coal interbeds; trace fluor sands, possibly disseminated in claystone. Sand (2040'-2100') = light to med light gray; very well to well sorted; fluor sand very fine, to very fine to fine upper; subround to subangular; high sphericity; dominant quartz with lithics meta sedimentary, common dark to light greenstone; unconsolidated, floating in clays; common detrital carbonaceous mater, coal macerals in claystone by 2100'; bulk calcareous possible mud add. Coal/ Carbonaceous Shale (2100'-2160') = black with brownish black secondary hues; very firm to moderately hard and brittle; platy to flaky; massive at times planar fracture dominant with trace conchoidal; smooth to gritty texture; earthy to resinous luster; poorly developed; sub lignitic; no outgassing present. Tuffaceous Claystone/ Tuffaceous Siltstone (2160' - 2220') = medium to medium light gray; soft to slightly firm; irregular to wedge shaped cuttings; silty to clayey texture; dull to slightly waxy luster; hydrophilic; moderate to very soluble; slight to moderately expansive; poor adhesiveness; poor to fair cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; common to abundant thin coal beds throughout interval. Sand (2220' - 2290') = medium light to light gray overall with individual liths dominantly clear to translucent quartz and volcanic glass, medium to dark gray and black; very fine lower to fine upper , dominantly fine lower; angular to subangular; moderately well sorted; dominantly unconsolidated with trace tuffaceous sandstone; very fragile; medium to light gray; very ashy matrix support; slight to moderately calcareous; continued thin coal beds throughout. Tuffaceous Claystone/ Tuffaceous Siltstone (2290' - 2350') = medium to medium light gray with very light brown to brownish gray and yellowish gray secondary hues; very soft to slightly firm; irregular, shapeless to wedge shaped cuttings with trace pdc bit action shaped; silty to clayey texture; dull to earthy luster; poor to fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sandstone/ Sand (2350' - 2400') = medium to medium light gray with a moderate to strong salt and pepper appearance with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass; hard to brittle; irregular, wedge shaped pieces; moderately well sorted; well consolidated; calcareous cement; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (2400' - 2470') = medium to medium light gray with very light brown secondary hues; very soft to slightly firm; irregular, shapeless to wedge shaped; silty to clayey texture; dull, earthy to greasy luster; poor cohesiveness; fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; continued trace to common thin coal beds throughout interval. Sand (2470' - 2540') = medium gray with a moderate salt and pepper appearance, individual grains medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to trace very coarse upper, dominantly fine upper to medium upper; angular to subangular; moderately well sorted; disaggregated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (2540' - 2600') = medium light to light gray with very light yellowish brown to yellowish gray secondary hues; very soft to fragile; irregular to shapeless cuttings; silty to clayey texture; dull to slightly greasy luster; moderately soluble; hydrophilic; poor cohesiveness; poor to fair cohesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; scattered thin coal beds throughout interval. Hilcorp Alaska, LLC Kolatsa 1 13 Sand (2600' - 2670') = medium gray with a moderate salt and pepper appearance, individual grains medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to coarse lower, dominantly fine upper to medium lower; angular to trace subrounded, dominantly subangular; unconsolidated; fair to good sorting; unconsolidated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (2670' - 2730') = medium to medium light gray with very light brown secondary hues; very soft to slightly firm; irregular, shapeless to wedge shaped; silty to clayey texture; dull, earthy to greasy luster; poor cohesiveness; fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds throughout interval. Sand (2700' - 2770') = medium dark gray with a weak salt and pepper appearance, individual grains 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 trace subrounded, dom inantly subangular; unconsolidated; fair to good sorting; unconsolidated; non calcareous. Coal (2770'-2790') = black; subbituminous; hard, brittle; thin blocky cuttings with slight hackly fracture; trace pyrite, very fine light brown plant debris; trace as rip up detritus in overlying siltstone. Tuffaceous Claystone (2790'-2835') = medium light to light gray with bluish gray hues; firm friable to soft, slightly pulverulent ashy colloidal clay; silty to smooth clayey texture; trace yellow disseminated particles; massive, open earthy fracture; occasional detrital carbona ceous mater; non calcareous. Sand (2840'-2860') = medium light gray; well to very well sorted; upper medium to very fine becomes fine to very fine; angular to subround; high to moderate sphericity; unconsolidated; pol ish, pitted to grind mechanical abrasion; dominant quartz, 20-30% dark to medium light gray lithics, dominant sedimentary to meta sedimentary; trace biotite. Tuffaceous Siltstone (2865'-2880') = medium dark gray with dark bluish gray hue; very firm; waxy, irregular subplaty cutting; dull, waxy luster; silty but phosphatic appearance; distinct lack of hydration. Sand (2880'-2940') = medium to medium light gray; well sorted; very fine to medium lower; dominant fine to very fine; angular to subround; high to moderate sphericity; polish, pitted to grind mechanical abrasion; unconsolidated, matrix gray to light brown increases detrital clay, carbonaceous mater with depth; dominant quartz, 5-10% dark gray lithics. Sand (2940'-3030') = medium to medium dark gray; well to moderate well sorted; very fine to medium; dominant very fine to fine; angular to subround; moderate to high sphericity; dominant quartz; 10-20% lithics, increases to 40% lithics @ 2970'; medium light soluble clay matrix support, unconsolidated. Tuffaceous Claystone (3040'-3070') = very light to medium light gray with occasional light brown gray hue; soft to pasty; colloidal, non-sectile; poor cohesion; low adhesion; easy soluble; suspended sand matrix, occasional silty, includes carbonaceous mater; trace black subbitum inous coal. Sand (3045'-3105') = medium dark gray; well sorted; very fine to medium; fine dominant; angular to subround; moderate to high sphericity; unconsolidated and loose; clay matrix support, easy soluble gray; dominant quartz; 20-30% dark gray lithics; trace biotite. Sand/ Sandstone (3105'-3210') = medium dark to medium light gray; well to very well sorted; very fine to medium; very fine to fine dominant; angular to subround; moderate to high sphericity; dominant quartz; 20% dark gray lithics, common includes coal clasts; moderate hard, dense grain supported sandstone very fine to fine, secondary laumonite in interstices @ 3210' bone; continued abundant associate d interstitial clay in loose and unconsolidated sands. Hilcorp Alaska, LLC Kolatsa 1 14 Coal (3230'-3270') = black; subbituminous thin coal stringers, increasing silty laminar cuttings common associated; blocky, to ragged cuttings com medium grain slightly rounded habits as sand c lasts; silty carbonaceous layer appears inter bedded with massive sand lobe. Tuffaceous Claystone (3270'-3300') = medium light gray; fairly homogenous finely sandy clay, pronounced at gas show @ 3290' with massive bedded appearance; reactive, soluble; poor cohesion and adhesion; very minor coal in samples; overall amorphous clays with well sorted sand disseminated. Sand (3300'-3345') = medium gray; very well sorted; very fine to fine; angular to subround; moderate to high sphericity; dominantly quartz, common plagioclase; 10-20% dark gray lithics; unconsolidated and loose; medium light gray clay matrix. Coal ( 3345'-3360') = black to dark brownish gray; subbituminous; blocky to subplanar, occasional subconchoidal cuttings; dull to resinous; smooth to slightly mottled, gritty fracture surfaces; no outgassing observed. Tuffaceous Claystone (3360'-3390') = medium light gray; pasty, soft; hydrated moderate colloidal, silty in part; nodular to tabular cuttings habits, clayey to moderately silty texture; suspended well sorted very fine to medium sands. Coal (3990'-3405') = black; subbituminous; moderately hard; brittle; blocky, to irregular open, to splintery fracture; resinous; some white splotches; no outgassing or sample fluorescence. Sand (3405'-3440') = medium gray; fairly well sorted; very fine to medium; angular to subround; moderate sphericity; dominant quartz, common plagioclase, 20-30% lithics; loose to disaggregated. Tuffaceous Claystone/ Tuffaceous Siltstone (3440' - 3560') = medium light to light gray with very light brown to light brownish gray secondary hues; very soft to trace slightly firm; irregular to shapeless, globular cuttings; slimy to mushy; silty to clayey texture; dull to greasy luster; hydrophilic; moderate to 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; trace thin coal beds. Sand (3560' - 3600') = medium gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black and clear to translucent quartz and volcanic glass; very fine upper to medium upper, dominantly fine upper; angular to subangular; moderately well sorted; unconsolidated; non calcareous. Coal (3600' - 3660') = black with brownish black secondary hues; very firm to hard and brittle; flaky to splintery; massive in part; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly silty luster; resinous to slightly earthy texture; sub bituminous to bituminous; occasionally grading to carbonaceous shale; no outgassing observed; present as thin beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (3660' - 3720') = medium light to light gray; very soft to firm; irregular to shapeless, globular cuttings; slimy to mushy; silty to clayey texture; dull to greasy luster; hydrophilic; moderate to 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; trace to common thin coal beds throughout interval. Sand (3720' - 3780') = medium gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black and clear to translucent quartz and volcanic glass; very fine upper to medium upper, dominantly fine upper; angular to subangular; moderately well sorted; unconsolidated; non calcareous; present as very minor component in dominantly claystone formation. Hilcorp Alaska, LLC Kolatsa 1 15 Tuffaceous Claystone/ Tuffaceous Siltstone (3780' - 3850') = medium light to light gray with very light brownish gray hues; very soft to slightly firm; irregular to shapeless, globular cuttings; slimy to mushy; silty to clayey texture; dull to greasy luster; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Tuffaceous Claystone/ Tuffaceous Siltstone (3850' - 3920') = medium light gray to light gray with very light brownish gray secondary hues; very soft; very sticky; shapeless, amorphous cuttings; slimy to mushy; silty to clayey texture; earthy to greasy to dull luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; trace dark brown to black microthin laminations and inclusions in rare firmer fragments; trace thin coal beds throughout interval. Coal (3920' - 3980') = black with brownish black secondary hues; very firm to hard and brittle; flaky to splintery; massive in part; planar fracture dominant with trace conchoidal and birdeye; smooth to slightly silty luster; resinous to slightly earthy texture; sub bituminous to bituminous; occasionally grading to carbonaceous shale; trace weak outgassing bubbles present. Sandstone (3990'-4020') = medium light gray with very light gray hue; moderate hard to firm friable; very fine grain supported; silty; angular to subround; moderate sphericity; weakl y calcareous; dominant quartz; trace dark lithics; grades to medium dark gray with bluish gray hue tuffaceous siltstone; trace pale yellow gray ash seams. Coal (4020'-4050') = black with brownish gray secondary hues; subbituminous to bituminous; hard to moderate hard; brittle and crunchy; resinous to weakly adamantine luster; thin dirty laminations to smooth; trace pinpoint outgas bubbles. Sand (4050'-4080') = medium dark gray; well sorted; very fine to lower coarse; dominant medium upper to fine lower; angular to subround; high sphericity; unconsolidated to disaggregated; dominant quartz; 20% medium to dark gray lithics; medium light gray clay matrix. Tuffaceous Siltstone (4080'-4100') = medium dark to medium gray; moderate hard to very firm; flaky to irregular platy cuttings habit; very finely sandy in part, calcareous in seams grading to calc areous arenite; resists hydration. Coal (4120'-4170') = black to brownish black; bituminous; moderate hard to hard; brittle, crunchy; splintery to lesser blocky fracture; resinous to weak adamantine luster; common white splotc hed; rare dirty shale partings; common pinpoint outgassing bubbles. Tuffaceous Claystone/ Sandstone (4170'-4230') = medium to very light gray; soft pasty easy hydrated clayey section with very fine to fine sand disseminated in clay matrix to slightly less reactive clay matrix supported sandstone and trace moderate hard grain supported sandstone with secondary calcite cement; dominant quartz; 10-20% lithics. Sandstone/ Sand (4230'-4290') = very light to medium dark gray; soft easy friable, silty matrix supported very fine to fine grain sandstone with common detrital coal clasts to unconsolidated, loose sand with mod well sorted, very fine to medium upper, dominant lower fine to upper fine; very angular to subround; dominant subangular to subround; moderate to high sphericity dominant; dominant quartz; 10-20% dark gray lithic clasts; interbeds moderate reactive tuffaceous claystone, thin bedded black bituminous coal stringers. Tuffaceous Claystone/ Siltstone (4390'- 4450') = medium light to bluish gray; soft to firm; pasty, clayey moderate silty texture, common disseminated very fine sand; tabular to nodular cuttings habit; massive with occasional thin silt bedding varves; low toc; slack non sectile; poor to moderate cohesion; low to slight adhesion. Hilcorp Alaska, LLC Kolatsa 1 16 Coal (4350'-4360') = black to brownish black; bituminous; splintery platy to blocky cuttings habit; good fissile planar to curved fracture; common white mineral on fracture surfaces, trace greenish amber vitreous crystal; good trace pinpoint outgassing. Sandstone (4360'-4470') = very light to medium light gray, pepper black lithics; easy to hard friable; laumonite to calcite cement; moderate well sorted; very fine to medium upper; dominant lower fine to medium lower; very angular to subround; dominant subangular; calcite to laumonite cement overgrowths; long and point contacts occasional; massive bedded; dominant quartz 10% dark lithics. Tuffaceous Claystone/ Tuffaceous Siltstone (4470'-4530') = medium light gray with light olive gray and light brownish gray secondary hues; soft to slightly firm; irregular, wedge to shapeless cuttings; silty to clayey texture; dull, earthy to slightly waxy luster; hydrophilic; moderately soluble and expansive; poor to fair cohesiveness and adhesiveness; trace dark brown to black microthin car bonaceous laminations and inclusions; trace to common coal beds. Sand/ Tuffaceous Sandstone (4530'-4600') = medium light to light gray overall with individual grains clear to translucent quartz and volcanic glass, trace medium to dark gray and black; very fine lower to medium upper, dominantly fine; angular to subangular; moderately well to well sorted; dominantly disaggregated with minor ashy tuff supported grains; very fragile matrix; non calcareous; very light gray to grayish white. Tuffaceous Claystone/ Tuffaceous Siltstone (4600'-4660') = medium light gray to light gray with very light brownish gray secondary hues; soft to slightly firm; irregular, wedge to shapeless cuttings; silty to clayey texture; dull, earthy to slightly waxy luster; hydrophilic; moderately soluble and expansive; poor to fair cohesiveness and adhesiveness; trace to common thin coal beds throughout interval. Tuffaceous Sandstone/ Sand (4660'-4720') = very light gray overall with a mottled appearance with darker gray, greenish gray and brownish gray secondary hues; very soft to fragile, pulverulent; irregular to shapeless cuttings; silty to gritty to abrasive texture; dull, earthy to sparkling luster; non calcareous; ash matrix supports loose sand grains; clear to translucent quartz and volcanic glass, trace dark gray liths; very fine upper to fine; angular to subangular; Sand/ Tuffaceous Sandstone (4720'-4780') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray and black; very fine upper to medium lower, dominantly fine; angular to subangular; very well sorted; very loosely consolidated in ashy tuff matrix very fragile; visible glass shards; non calcareous; trace very thin coal beds. Tuffaceous Sandstone/ Sand (4780'-4850') = very light gray overall with a mottled appearance with darker gray, greenish gray and brownish gray secondary hues; very soft to fragile, pulverulent; irregular to shapeless cuttings; silty to gritty to abrasive texture; dull, eart hy to sparkling luster; non calcareous; ash matrix supports loose sand grains; clear to translucent quartz and volcanic glass; trace dark gray liths; very fine upper to fine; angular to subangular; trace dark brown carbonaceous shale/ material. Tuffaceous Claystone/ Tuffaceous Siltstone (4850' - 4910') = medium light brownish gray with light olive gray secondary hues; soft to slightly firm to fragile; irregular, wedge with trace pdc bit action shaped cuttings; silty to clayey to slightly gritty texture; dull to earthy luster; slight to moderately soluble and expansive; fair cohesiveness; poor adhesiveness; trace dark brown to black carbonaceous material/ coal beds. Sand/ Tuffaceous Sandstone (4910'-4970') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray, black and pale rose; very fine lower to medium lower, dominantly fine upper to lower; angular to subround dominantly subangular; very well sorted; loosely consolidated in ashy tuff matrix very fragile; visible glass shards; non to slightly calcareous Hilcorp Alaska, LLC Kolatsa 1 17 Coal/ Carbonaceous Shale (4970'-5030') = black with brownish black secondary hue; hard to brittle; blocky to platy; massive at times; planar fracture dominant; smooth to slightly gritty texture; resinous to slightly earthy luster; sub bituminous to bituminous; no to weak trace outgassing bubbles observed; dominantly present as thin beds in tuffaceous sand formation. Tuffaceous Siltstone/ Tuffaceous Claystone (5030' - 5090') = medium light brownish gray with light olive gray secondary hues; soft to fragile; irregular with pdc bit action shaped cuttings; silty to slightl y gritty texture; earthy to dull luster; non calcareous; poor to fair cohesiveness; poor adhesiveness; brownish gray siltstone commonly grades between silty sandstone and sandy siltstone; trace thin coal beds throughout. Sand/ Tuffaceous Sandstone (5070'- 5115') = very light gray, white; very well sorted; lower very fine to lower medium; dominant lower upper fine to upper fine; subangular to subround; disaggregated from ash matrix to consolidated, cement overgrowths with long contact fabrics; cement non calcareous to pinpoint calcareous. Coal (5115'-5130') = black to dark gray; sub bituminous with secondary bituminous 5-8 mm laminar seams; hard, brittle and crunchy; resinous to dull; irregular platy to slightly mottled; incipient fissil ity; trace outgassing bubbles. Sand/ Sandstone (5130'-5190') = very light gray; moderate well to fair sort; upper very fine to coarse lower; dominant upper fine to medium upper; very angular to subround; dominant angular; low to moderate sphericity; quartz dominant; disaggregated with common quartz overgrowths; sandstone moderate tight, occluded with laumonite with increasing common point contacts in overall long contact fabric; moderate porous, permeability; non calcareous dom. Sand/ Sandstone (5140'-5190') = very light gray; moderate well to well sort; very fine to medium; angular to subround; moderate to low sphericity; disaggregate to tight laumonite cement aggregates with increase overgrowths quartz common trace point contact fabrics with good evident porosity and permeability; dominant quartz, common feldspar; 5% lithics occasional including coal rip ups. Tuffaceous Claystone (5300'-5330') = light brown gray; firm to soft; low density; nodular to tabular; dull to earthy; detrital silt common smooth slight sectile; good cohesion; poor adhesion; poor soluble ; low reactive. Coal (5340'-5360') = black to brownish black with microsparkle silt; hard to moderate hard; brittle; bituminous; splintery to blocky, platy plumb to bedding; resinous to vitreous; includes trace argillaceous infills with thin needles coal disseminated; no outgas. Sand (5360'-5400') = very light gray; well sorted; very fine to medium lower; angular to subround; moderate to high sphericity; disaggregated from soft white ashy matrix to occasional cement aggregates with occluded interstices with non-calcareous white cement overgrowths; dominant quartz; 10% lithics. Coal (5450'-5470') = black to brownish black; hard; blocky to splintery; sub bituminous to bituminous; resinous to vitreous; dirty to slight silty lens laminar bitum inous layers <1cm. Coal (5470' - 5530') = black with brownish black secondary hues; hard to brittle; platy to blocky; planar fracture dominant; smooth to slightly silty texture; resinous to earthy luster; bituminous; vigorous outgassing in larger fragments; coal grades to carbonaceous shale. Tuffaceous Claystone (5530'-5545') = light bluish gray with medium light gray hue; firm; moderate sectile; tabular to nodular; smooth clayey texture; thin friable very fine sandstone interbeds; minor grades to tuff siltstone. Hilcorp Alaska, LLC Kolatsa 1 18 Sandstone/ Tuffaceous Sand (5550'-5600') = very light gray, varied heavy to light peppered appearance from varied black, medium gray to green lithics; easy to hard friable; pinpoint effervescence to HCl; occluded white cement overgrowths silicate with some long to point contact fabrics; well sorted; very fine to medium; very angular to subround; moderate to high sphericity; moderate soluble ash matrix when unconsolidated; moderately porous. Tuffaceous Siltstone (5610'-5650') = medium light to very light gray with olive gray hues; firm friable; argillaceous dirty grades to claystone, includes wispy disseminated black coal, grading to very fine to fine carbonaceous silty sandstone; tabular to nodular cuttings habit; massive to slight graded; thin black coal beds, dirty claystone also thin; non calcareous to pinpoint. Coal (5670'-5680') = black, medium dark gray siltstone laminar with discontinuous coals; hard; brittle to crunchy; blocky with sub conchoidal to trace planar fracture; carbonaceous siltstone thin sandstone interbeds, dirty moderate brown claystone appears turbid argillaceous, finely arenaceous and silty. Tuffaceous Siltstone (5680’ -5760’) = light brownish gray with olive hues; firm friable; moderate clayey silty, common very finely arenaceous, grades to very fine to fine friable san dstone; tabular to nodular to occasional scaly cuttings habit; dom inant non calcareous; common floating carbonaceous mater. Sandstone/ Sand/ Coal (5760'-5835') = very light gray to white to slightly peppered, translucent, colorless, cloudy with <10% gray, black to green; fine to very fine cement, to easy friable with occluded white cement overgrowths and turbid carbonaceous mater grading to siltstone, becomes mass ive unconsolidated with initial poor to fines down to well sorted, increase white cement overgrowths, occasional frosted to etched; dominant quartz, cement weakly calcareous to non-calcareous; from 5780' to 5795' coarse to very fine, dominant medium to fine, fines down to very fine to medium with dominant fine; very angular to subround; moderate to high sphericity dominant with low sphericity fresh clear quartz com; coal @ base abrupt, silty laminar to mass bitum inous. Tuffaceous Sandstone (5860'-5900') = very light gray, white to bluish white; easy friable to soft clayey ashy; very well sorted; very fine to fine; subround to subangular; occluded, low porosity with varied soft, ash to argillaceous matrix support. Coal (5895'-5910') = black to brownish black; bituminous, hard, tough to crunchy; large cuttings, with conchoidal to sub conchoidal fracture, elongated with very fine undulatory fibrous appearance; resinous, vitreous with weak adamantine hue; visible out gassing. Tuffaceous Claystone/ Coal (5910'-5980') = light brownish gray tuffaceous claystone intercalated with common color mottled brown to gray white s iltstone, dirty sandstone; thin coals common, black with increase bituminous grades; mixed claystone, siltstone varied very finely arenaceous sandy to smooth clayey texture, nodular to tabular; good to moderate cohesion, poor adhesion. Tuffaceous Siltstone (5980'-6050') = light brown gray with medium gray hue; firm to friable; tabular, nodular; grade to silty sandstone, turbid in part with carbonaceous mater; silty to clayey texture; good cohesion; non calcareous. Tuffaceous Sandstone (6050' - 6090') = white to bluish white; soft, clayey to easy friable; well sort; very fine to fine; subround to subangular; quartz overgrowths to dominant white occluded ash to silicate cement; weak calcareous. Coal/ Carbonaceous Shale (6090'-6150') = black with trace brownish black secondary hues; hard, brittle at times; platy to splintery; massive at times; planar fracture dominant with trace con choidal and birdeye; smooth to slightly silty texture; resinous to occasionally earthy luster; trace outgassing bubbles observed; coal commonly grades to a carbonaceous shale; silty and earthy; very firm hard; overall bituminous. Hilcorp Alaska, LLC Kolatsa 1 19 Tuffaceous Siltstone/ Tuffaceous Claystone (6150' - 6220') = light brownish gray to medium light gray with light olive gray secondary hues; soft to fragile; irregular with trace pdc bit action shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy luster; slight to moderately soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; siltstone commonly grades between sandy siltstone and silty sandstone; soft to fragile. Tuffaceous Sandstone/ Sand/ Sandstone (6220' - 6290') = dirty white appearance from dark gray and brown secondary hues; very fragile to soft; irregular shaped; ashy matrix supports fine sand grains; dominantly clear to translucent quartz and volcanic glass; angular to subangular; moderately well sorted; non calcareous; common thin coal beds throughout. Tuffaceous Sandstone/ Sand/ Conglomerate (6290' - 6340') = very light gray to grayish white; ashy matrix very uniform white; fragile to pulverulent; irregular individual sand grains dominantly clear to translucent quartz and volcanic glass trace dark gray to black, pale green and pale rose; very fine lower to very coarse upper, dominantly fine lower to medium lower; poorly sorted; angular to trace subrounded, dominantly subangular; very loosely supported by ash matrix; moderate calcareous cement. Tuffaceous Siltstone/ Tuffaceous Claystone (6150' - 6220') = light brownish gray to medium light gray with brownish gray secondary hues; soft to fragile; irregular with trace pdc bit action shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy luster; slight to moderately soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Tuffaceous Sandstone/ Sand (6220'-6460') = grayish white; ashy matrix very uniform white; fragile to pulverulent; irregular individual sand grains dominantly clear to translucent quartz and volcanic glass trace dark gray to black, pale green and pale rose; very fine lower to medium upper, dominantly fine; angular to subangular; moderately well sorted; very loose ashy matrix support. Coal (6460' - 6530') = black; hard to brittle; flaky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster; bituminous; vigorous and prolonged outgassing bubbles observed. Tuffaceous Siltstone/ Tuffaceous Claystone (6530' - 6590') = light olive gray to light brownish gray with light gray and light yellowish gray secondary hues; very soft to fragile; irregular to tabular and trace pdc bit action shaped; silty to clayey texture; dull, earthy luster; poor cohesiveness ; poor to fair adhesiveness; non calcareous; siltstone commonly grades between a fragile sandy siltstone and silty sandstone; trace to common thin coal beds throughout zone. Tuffaceous Siltstone/ Sandstone (6590'- 6650') = dirty light brownish gray to light bluish gray with grayish white to olive hues; firm friable to soft, moderate hydrated, smooth to finely arenacous with thin tight grain to matrix supported very fine to fine sandstone, ashy to weakly calcareous; nodular to tabular cuttings, common scaly to blocky tight sandstone. Tuffaceous Sandstone (6660'-6730') = grayish white to very light gray common bluish white hues; moderate well to fair sorted; very fine to coarse; dominant medium to fine, grades to very fine to fine; very angular to subround; dominant subangular to angular; very occluded ash, soft cement with overgrowths of point contacts common to also long contact fabric also overgrown with cement, weakly calcareous cement dominant white chalky silicate; dominant quartz, occasional plagioclase, <10% black to dark gray, pink to green lithic fragments dominant volcanics, meta sedimentary; trace chlorite, green accessory minerals; trace mineral fluorescence. Hilcorp Alaska, LLC Kolatsa 1 20 Coal (6740'-6770') = pitch black; bituminous; conchoidal to blocky; irregular smooth to laminar needle habits; hard to brittle; thin bed @ 6740', by 6770' mixed with brownish gray carbonaceous shale/ claystone with disseminated clastic to laminar coal; visible outgas. Sandstone (6780-6800') = very light gray to bluish gray; soft, chalky ash matrix unconsolidated; very fine to fine; subangular to subround; moderate to high sphericity; very well sorted; dominant quartz; 2% lithics; occluded cement with point to point overgrowths; weakly calcareous; accessory green to yellow minerals; no sample fluorescence. Coal (6800'-6840') = black to dark gray to brownish gray; dominant bitum inous, with sub bituminous to slight dirty; moderate hard to hard; brittle, tough to crunchy; subconchoidal to blocky, common blunt; trace translucent green/orange/amber m ineral inclusion; moderate pinpoint outgassing. Sandstone (6840'-6930') = light brown to very light gray, white; soft, clayey matrix holding very poor sorted, very fine to granule; friable with chalky silicate cement; unconsolidated with good frosting; well- rounded granules dominant subangular to subround; fines overall by 6900' to very well sort very fine to fine; pepper black, green, some yellow, red to gray; dominant quartz; granules mix felsic plutonic , smokey to volcanic quartz, greenstone, basalt; fair porous and permeability cemented to ashy/clayey, rare calcite; trace chlorite sheets, occasional biotite specks. Tuffaceous Siltstone (6970'-7000') = olive to medium gray light brown hues; soft smooth, clayey to silty; very finely sandy in part; tabular to nodular; low dense; moderate reactive, hydrophilic; poor soluble; moderate cohesion; poor adhesion; non calcareous; wispy carbonaceous matter; grades to fine grain sandstone. Tuffaceous Siltstone/ Tuffaceous Claystone (7020' - 7100') = light olive gray to light brownish gray with light gray and light yellowish gray secondary hues; very soft to fragile; irregular to tabular and trace pdc bit action shaped; silty to clayey texture; dull, earthy luster; moderately soluble, easily washed away; poor cohesiveness; poor to fair adhesiveness; non calcareous; common to abundant thin coal beds throughout. Coal (7100' - 7150') = black; hard to brittle; flaky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster; bituminous; trace to c ommon outgassing bubbles. Tuffaceous Sandstone/ Sand (7150'-7200') = grayish white; fragile to pulverulent; individual sand grains dominantly clear to translucent quartz and volcanic glass, trace dark gray to black and light greenish gray; very fine lower to medium upper, dominantly fine; angular to subangular; moderately well sorted; very fragile ashy matrix supported grains; common to abundant coal beds throughout. Tuffaceous Siltstone/ Tuffaceous Claystone (7200' - 7270') = light olive gray to light brownish gray with light gray and light yellowish gray secondary hues; very soft to fragile; irregular to wedgelike and trace pdc bit action shaped; silty to clayey texture; dull, earthy luster; poor cohesiveness; poor to fair adhesiveness; non calcareous; siltstone commonly grades between a fragile sandy siltstone and silty sandstone; trace to common thin coal beds throughout zone. Tuffaceous Siltstone/ Tuffaceous Claystone (7270' - 7340') = light gray to yellowish gray with light olive gray and light brownish gray secondary hues; soft, fragile; irregular to shapeless cuttings with trace pdc bit action scooped appearance; silt y to clayey to slightly gritty texture; dull, earthy luster; slight to moderately soluble; poor cohesiveness; poor to fair adhesiveness; non calcareous; siltstone grades between sandy siltstone and sandy siltstone; very fragile; non calcareous; common to abundant thin coal beds throughout interval. Hilcorp Alaska, LLC Kolatsa 1 21 Sand/ Tuffaceous Sandstone (7340'-7400') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, light green to greenish gray and black; very fine lower to fine upper; angular to subrounded, dominantly subangular; moderate to very well sorted very friable; very loosely supported grains from ashy matrix; white; pulverulent; non calcareous; continued thin coal beds throughout interval. Tuffaceous Siltstone/ Tuffaceous Claystone (7020' - 7100') = light olive gray to medium light gray with light brownish gray and yellowish gray secondary hues; very soft to fragile; irregular shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy luster; poor cohesiveness; poor to fair adhesiveness; non calcareous; siltstone commonly grades between silty sandstone and sandy siltstone; very fragile. Coal (7100' - 7150') = black; hard to brittle; flaky to platy; planar fracture dominant with trace conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster; bituminous; trace to common outgassing bubbles. Tuffaceous Sandstone/ Sand (7150'-7200') = grayish white; fragile to pulverulent; individual sand grains dominantly clear to translucent quartz and volcanic glass trace dark gray to black and light greenish gray; very fine lower to medium upper, dominantly fine; angular to subangular; moderately well sorted; very fragile ashy matrix supported grains; common to abundant coal beds throughout. Tuffaceous Siltstone/ Tuffaceous Claystone (7200' - 7270') = light olive gray to light brownish gray with light gray and light yellowish gray secondary hues; very soft to fragile; irregular to wedgelike and trace pdc bit action shaped; silty to clayey texture; dull, earthy luster; poor cohesiveness ; poor to fair adhesiveness; non calcareous; siltstone commonly grades between a fragile sandy siltstone and silty sandstone; trace to common thin coal beds throughout zone. Tuffaceous Siltstone/ Tuffaceous Claystone (7270' - 7340') = light gray to yellowish gray with light olive gray and light brownish gray secondary hues; soft fragile; irregular to shapeless cuttings with trace pdc bit action scooped appearance; silty to clayey to slightly gritty texture; dull, earthy luster; slight to moderately soluble; poor cohesiveness; poor to fair adhesiveness; non calcareous; siltstone grades between sandy siltstone and sandy siltstone; very fragile; non calcareous; common to abundant thin coal beds throughout interval. Sand/ Tuffaceous Sandstone (7340'-7400') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, light green to greenish gray and black; very fine lower to fine upper; angular to subrounded, dominantly subangular; moderate to very well sorted very friable; very loosely supported grains from ashy matrix; white; pulverulent; non calcareous; continued thin coal beds throughout interval. Tuffaceous Siltstone/ Tuffaceous Claystone (7020' - 7100') = light olive gray to medium light gray with light brownish gray and yellowish gray secondary hues; very soft to fragile; irregular shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy luster; poor cohesiveness; poor to fair adhesiveness; non calcareous; siltstone commonly grades between silty sandstone and sandy siltstone; very fragile. Carbonaceous Claystone/ Claystone (7470'-7525) = brownish gray to brownish black , dusky yellow brown hue; very firm to friable; argillaceous, moderate silty arenaceous coal; clayey texture; subtabular to smooth pdc cuttings habit, coaly markings on edge; trace thin lens olive gray silt; carbonaceous fine grain sandstone @7510'; black carbonaceous, banded coaly interbeds with black bituminous coal; non calcareous. Hilcorp Alaska, LLC Kolatsa 1 22 Sand/ Sandstone (7560'-7605') = very light gray, light brown to gray white hue; soft ashy matrix at top, unconsolidated with depth; fairly well to well sorted; initial very fine to coarse lower; becomes very fine to medium upper, dominant lower medium to upper fine; very angular to subround; dominant subangular to subround; moderate to high sphericity; dominant quartz, clear cloudy to translucent; 2% lithics; weak calcareous. Tuffaceous Siltstone (7605'-7655') = olive to light brown gray; soft, clayey smooth to silty; tabular to nodular; open earthy fracture; moderate cohesion; low adhesion; dull to earthy; occasional colloidal, slimy, greasy; non calcareous. Sandstone (7655'-7710') = very light gray, bluish white, dirty light brown; peppered appearance; soft pasty to easy friable; dirty light brown, arenaceous silt, clay and carbonaceous mater; very well sorted; silt to fine; dominant very fine; angular to subround; dominant subangular to subround; moderate to high sphericity; occluded silicate overgrowths at bone, to common dirty friable grain supported, hydrated ashy soft; variable moderate to low porosity and permeability. Coal (7710'-7735') = black, brownish black; hard to moderate hard; crunchy to brittle; bituminous to sub bituminous; elongate to irregular subconchoidal to sp lintery fracture, occasional blunt edges; thin needle laminar; resinous to slightly vitreous; visible outgassing. Claystone (7770'-7785') = brown gray to brownish black; very firm; arenaceous fabric includes silty texture lighter olive gray hues, with an interbedded medium dark gray carbonaceous very fine grain, friable sandstone; tabular to nodular, common smooth pdc habit. Tuffaceous Sandstone (7800'-7830') = color mottled light gray to grayish white; soft, colloidal ash matrix to lesser chalky silicate cement; very well to well sorted; very fine to medium; dominant very fine to fine; angular to subround; dominant quartz; grades to friable very fine grain sandstone with fine coal disseminated; vary very to pinpoint calcareous. Sandstone (7850'-7935') = dirty light to medium light gray, gray white to white; easy friable, to chalky white to ashy cement varied colloidal, soluble to non-soluble; very well to fair sorted; very fine to fine, coarsens down to very fine to upper coarse, scattered very coarse by 7920'; very angular to subround; dominant subround to subangular; high to moderate sphericity; unconsolidated and loose with depth; cement weak to non-calcareous; friable carbonaceous very fine sandstone @ base, overlying black coal. Tuffaceous Siltstone/ Tuffaceous Claystone ( 7940' - 8000') = olive gray to light olive gray to light brownish gray with medium light gray secondary hues; irregular, sub discoidal with trace pdc bit action shaped cuttings; soft to slightly firm, fragile to pulverulent at times; silty to clayey to gritty texture dull, earthy luster; poor to fair cohesiveness; poor adhesiveness; non calcareous; siltstone commonly grades between sandy siltstone and silty sandstone; abundant coal beds throughout interval. Tuffaceous Sandstone/ Sand/ Conglomerate (8000' - 8080') = very light gray to grayish white; ashy matrix very uniform white; fragile to pulverulent; with individual sand grains dominantly clear to translucent quartz and volcanic glass trace dark gray to black, pale green and pale rose; very fine lower to very coarse upper, dominantly fine lower to medium lower; poorly sorted; angular to trace subrounded, dominantly subangular; very loosely supported by ash matrix; moderate to very calcareous cement; abundant thin coal beds throughout interval. Tuffaceous Sandstone/ Sand/ Conglomerate (8080' - 8170') = very light gray to grayish white with very light gray secondary hues for a mottled appearance; very fragile and pulverulent; with individual sand grains dominantly clear to translucent quartz and volcanic glass, trace dark gray to black, pale green and pale rose; very fine lower to trace very coarse upper, dominantly fine to medium lower; fair sorting; angular to trace subrounded, dominantly subangular; very loosely supported by ash matrix; non calcareous cement; trace thin coal beds. Hilcorp Alaska, LLC Kolatsa 1 23 Tuffaceous Siltstone/ Tuffaceous Claystone (8170' - 8220') = olive gray to light olive gray to light brownish gray; irregular, sub discoidal with trace pdc bit action shaped cuttings; soft to slightly firm, fragile to pulverulent at times; silty to clayey to gritty texture dull, earthy luster; poor to fair cohesiveness; poor adhesiveness; non calcareous; siltstone commonly grades between sandy siltstone and silty sandstone. Tuffaceous Sandstone/ Sand (8220'-8280') = medium light gray overall with a mottled appearance; very fragile, pulverulent; individual grains dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, greenish gray and pale rose; very fine upper to trace very coarse, dominantly fine; angu lar to subangular; moderately well sorted; very loosely supported by ashy matrix; non calcareous; trace coal beds. Coal (8280' - 8320') = black with trace grayish black and brownish black secondary hues; very firm to moderately hard and brittle; flaky to platy; planar fracture dominant with conchoidal and birdeye common; smooth texture; resinous luster; well developed; bituminous; prolonged outgassing bubbles observed. Tuffaceous Sandstone/ Sand (8320'-8400') = very light gray to grayish white with very light gray and light olive gray secondary hues for a mottled appearance; very fragile and pulverulent; with individual sand grains dominantly clear to translucent quartz and volcanic glass, trace dark gray to black, pale green and pale rose; very fine lower to coarse lower, dominantly fine lower to medium lower fair to good sorting; very loosely consolidated with ashy white matrix; non calcareous. Tuffaceous Sandstone/ Sand/ Conglomerate (8400' - 8460') = very light gray to grayish white with very light gray secondary hues; very fragile, pulverulent; individual sand grains dominantly clear to tr anslucent quartz and volcanic glass, trace dark gray to black, pale green and pale rose; very fine lower to trace very coarse upper, dominantly fine to medium angular to trace subrounded, dominantly subangular; moderate to low sphericity; overgrowth cement on few aggs to dominantly clean unconsolidated, moderate solution frost; weak to moderately calcareous; Sand/ Tuffaceous Sandstone/ Sandstone (8460-8560') = varied colorless, translucent, milky dominant quartz with dark gray, pink, green to black; varied poor to very well sorted; massive slight graded bedding, from very coarse to very fine, fines to dominant medium to fine with very fine to coarse range, also fines in part to very fine to fine; unconsolidated, white varied colloidal ash to chalky silicate cement overgrowth to occasional easy friable, abundant arenaceous very fine coal with rare thin coal laminae; very angular to subangular dominant, occasional well rounded; moderate to low sphericity dominant; dominant quartz, occasional dipyramidal; lithics mix of plutonic, basaltic to felsic volcanics; calcareous pinpoints common, particularly in ash matrix; trace mineral fluorescence. Sand/ Tuffaceous Sandstone/ Sandstone (8560-8630') = colorless, transparent, translucent to cloudy with scattered green, black, pink to dark gray; varied well to poor sorted; very fine to very coarse; very angular to subround; dominant angular to subangular; low to moderate sphericity; unconsolidated to varied marble white to dirty very light gray to light brown; silicate to colloidal ash matrix to unconsolidated with some frosting; massive with graded fining up from conglomerates. Sandstone (8670'-8720) = grayish white to very light gray; well to very well sorted; very fine to medium lower; dominant very fine lower to lower fine; angular to subround; moderate to high sphericity; fria ble, soft chalky to occasional colloidal ashy matrix; rare slight dirty argillaceous, silty; cement overgrowths, point contact fabrics; pinpoint calcareous common. Coal/ Carbonaceous Shale (8750-8760') = black to moderate brown gray; hard to very firm; bitum inous subconchoidal to tabular shaley nodular habits with argillaceous texture, disseminated coal; smooth, resinous to vitreous to earthy. Hilcorp Alaska, LLC Kolatsa 1 24 Sandstone/ Sand (8760'-8800') = very light gray white; colorless, translucent to cloudy dominant; unconsolidated to chalky white cement overgrowths; fairly well to well sorted; very fine to coarse lower; dominant fine upper to very fine upper; very angular to subround; dominant quartz, trace black yellow to green accessory minerals, lithics; pinpoint calcareous. Sandstone (8800'-8866') = very light gray, white to light brown hue; soft chalky easy friable; fair to well sort; angular to subround; very fine to very coarse, dominant medium lower to lower fine; dominant quartz; dirty to cement overgrowths; pinpoint calcareous. Hilcorp Alaska, LLC Kolatsa 1 25 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution 1 Washed and Dried Reference 134’ – 8000’ 8000’ – 8866’ 30’ 20’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 2 Washed and Dried Reference 134’ – 8000’ 8000’ – 8866’ 30’ 20’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 3 Washed and Dried Reference 134’ – 8000’ 8000’ – 8866’ 30’ 20’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 4 Washed, wet coal samples 2130’,3360’, 3920’, 4360’ 5013’,5355’ 5415’,5430’ 5450’,5610’ 5745’ Spot samples Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Hilcorp Alaska, LLC Kolatsa 1 26 4 DRILLING DATA 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 195.22 0.28 275.72 195.22 0.04 -0.43 0.32 0.16 263.52 2.31 315.25 263.50 1.04 -1.57 1.83 3.08 325.10 4.83 319.69 324.96 3.90 -4.12 5.66 4.12 386.70 7.73 317.80 386.18 8.94 -8.58 12.39 4.72 447.98 10.78 315.94 446.65 16.12 -15.34 22.25 5.00 510.98 13.60 315.10 508.05 25.57 -24.64 35.50 4.49 573.09 16.00 315.15 568.27 36.85 -35.86 51.40 3.86 633.10 18.09 314.45 625.64 49.24 -48.35 68.98 3.50 695.70 20.05 314.84 684.80 63.61 -62.90 89.41 3.13 757.81 21.40 314.97 742.89 76.13 -78.46 111.37 2.18 821.49 23.57 316.58 801.73 96.59 -95.44 135.72 3.54 883.95 24.41 316.45 858.79 115.02 -112.91 161.11 1.35 947.79 25.60 316.49 916.64 134.59 -131.50 188.09 1.86 1010.08 27.33 316.77 972.40 154.77 -150.55 215.85 2.79 1073.01 30.20 317.73 1027.56 177.01 -171.10 246.13 4.63 1136.26 33.54 318.52 1081.27 201.88 -193.38 279.52 5.32 1198.36 36.45 319.23 1132.14 228.71 -216.80 315.11 4.72 1262.27 38.76 319.11 1182.77 258.22 -242.30 354.09 3.62 1324.77 41.81 319.76 1230.44 288.91 -268.56 394.46 4.92 1386.41 44.61 319.69 1275.36 321.11 -295.85 436.62 4.55 1448.31 46.17 319.98 1318.83 354.78 -324.27 480.63 2.54 1481.69 47.24 320.05 1341.72 373.40 -339.88 504.90 3.21 1511.89 47.92 320.30 1362.09 390.52 -354.16 527.17 2.33 1574.42 47.56 317.87 1404.15 425.49 -384.46 573.41 2.94 1636.86 47.07 316.40 1446.48 459.13 -415.68 619.31 1.89 1698.99 46.81 315.83 1488.90 491.85 -447.15 664.70 0.80 1761.06 47.40 315.96 1531.15 524.50 -478.80 710.16 0.96 1824.06 45.95 315.12 1574.38 557.21 -510.90 755.97 2.50 1886.84 45.01 314.84 1618.39 588.85 -542.56 800.69 1.54 1948.76 45.02 314.43 1662.17 619.62 -573.72 844.44 0.47 2010.25 45.10 314.32 1705.60 650.05 -604.83 887.91 0.19 2072.96 45.58 313.41 1749.69 680.96 -636.99 932.44 1.28 2134.62 45.85 313.45 1792.74 711.31 -669.04 976.48 0.44 2194.77 46.17 312.95 1834.52 740.93 -700.59 1019.65 0.80 Hilcorp Alaska, LLC Kolatsa 1 27 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2257.93 46.99 312.63 1877.94 772.09 -734.26 1065.39 1.35 2318.65 45.95 314.83 1919.76 802.51 -766.07 1109.32 3.14 2382.07 44.82 316.50 1964.30 834.79 -797.62 1154.44 2.59 2440.99 45.25 316.33 2005.94 864.99 -826.36 1196.13 0.76 2506.95 45.78 315.94 2052.16 898.91 -858.97 1243.18 0.92 2570.19 45.80 317.31 2096.25 931.86 -890.11 1288.51 1.55 2633.27 46.37 316.66 2140.00 965.08 -921.11 1333.94 1.17 2695.49 46.71 318.79 2182.81 998.50 -951.49 1379.10 2.55 2758.03 46.82 320.20 2225.64 1033.14 -981.08 1424.63 1.65 2821.15 47.48 319.85 2268.57 1068.60 -1010.81 1470.85 1.13 2882.48 46.29 320.27 2310.49 1102.92 -1039.56 1515.56 2.00 2944.11 46.88 320.45 2352.84 1137.40 -1068.11 1560.26 0.98 3006.90 47.45 319.64 2395.53 1172.69 -1097.68 1606.25 1.32 3067.28 45.89 319.73 2436.96 1206.19 -1126.10 1650.13 2.60 3129.10 46.22 318.54 2479.86 1239.85 -1155.22 1694.62 1.49 3190.56 46.57 318.49 2522.25 1273.18 -1184.70 1739.11 0.57 3253.94 47.27 317.90 2565.54 1307.69 -1215.56 1785.39 1.29 3316.38 47.03 317.52 2608.00 1341.56 -1246.36 1831.17 0.59 3378.48 45.09 317.52 2651.09 1374.54 -1276.56 1875.89 3.12 3440.78 45.23 317.11 2695.02 1407.01 -1306.51 1920.06 0.52 3504.14 45.97 317.07 2739.34 1440.15 -1337.32 1965.31 1.17 3566.32 46.32 316.25 2782.44 1472.77 -1368.11 2010.16 1.11 3627.95 47.06 316.06 2824.71 1505.11 -1399.17 2055.00 1.21 3690.90 46.83 317.60 2867.69 1538.65 -1430.64 2100.99 1.83 3752.70 45.62 317.05 2910.44 1571.46 -1460.88 2145.61 2.07 3815.33 45.43 318.05 2954.32 1604.43 -1491.05 2190.30 1.18 3877.76 44.26 316.76 2998.59 1636.85 -1520.84 2234.32 2.38 3938.72 42.21 315.98 3043.00 1667.07 -1549.64 2276.07 3.47 4000.74 40.99 316.27 3089.37 1696.75 -1578.18 2317.24 1.98 4061.95 40.09 317.40 3135.89 1725.77 -1605.40 2357.02 1.90 4123.68 38.99 317.21 3183.49 1754.65 -1632.05 2396.32 1.80 4186.92 38.76 318.20 3232.73 1784.01 -1658.76 2436.01 1.05 4249.34 36.58 318.64 3282.14 1812.54 -1684.07 2474.14 3.52 4311.12 34.55 318.40 3332.39 1839.46 -1707.87 2510.06 3.29 4373.95 33.68 317.59 3384.41 1865.64 -1731.45 2545.29 1.56 4435.69 32.09 317.82 3436.26 1890.43 -1754.01 2578.81 2.58 4497.84 31.17 316.72 3489.17 1914.38 -1776.12 2611.40 1.75 4560.54 31.50 317.19 2542.72 1938.21 -1798.37 2644.01 0.66 4624.06 30.41 317.31 3597.20 1962.20 -1820.55 2676.68 1.72 Hilcorp Alaska, LLC Kolatsa 1 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4685.71 29.91 318.88 3650.50 1985.25 -1841.24 2707.66 1.52 4745.90 28.29 319.46 3703.09 2007.40 -1860.39 2736.91 2.73 4809.53 27.10 317.89 3759.43 2029.61 -1879.91 2766.47 2.19 4872.41 25.13 317.56 3815.89 2050.09 -1898.53 2794.15 3.14 4934.90 23.21 318.41 3872.89 2069.10 -1915.66 2819.73 3.14 4996.97 21.01 317.54 3930.40 2086.46 -1931.29 2843.10 3.58 5059.09 19.48 316.81 3988.67 2102.23 -1945.90 2864.59 2.50 5120.84 19.58 315.88 4046.87 2117.17 -1960.15 2885.24 0.53 5184.46 17.90 316.73 4107.12 2131.94 -1974.28 2905.67 2.68 5246.13 16.52 316.75 4166.02 2145.22 -1986.78 2923.92 2.23 5307.58 14.89 319.06 4225.18 2157.55 -1997.94 2940.54 2.85 5369.98 13.42 316.37 4285.68 2168.85 -2008.19 2955.80 2.57 5430.89 13.49 315.35 4344.92 2179.02 -2018.06 2969.97 0.41 5493.64 12.29 316.34 4406.08 2189.06 -2027.82 2983.97 1.95 5556.54 11.35 319.99 4467.66 2198.65 -2036.42 2996.84 1.91 5618.10 9.80 316.71 4528.17 2207.10 -2043.91 3008.13 2.70 5680.12 8.66 316.35 4589.38 2214.32 -2050.75 3018.07 1.83 5742.04 7.11 315.62 4650.71 2220.43 -2056.65 3026.57 2.52 5804.08 6.15 319.76 4712.34 225.71 -2061.48 3033.73 1.72 5867.09 5.45 322.03 4775.03 2230.65 -2065.50 3040.08 1.17 5928.35 4.50 312.89 4836.05 2234.58 -2069.05 3045.38 2.02 5991.60 2.82 304.46 4899.17 2237.15 -2072.16 3049.37 2.77 6053.84 1.42 273.43 4961.37 2238.06 -2074.19 3051.42 2.84 6116.38 1.01 172.83 5023.91 2237.56 -2074.89 3051.53 3.01 6178.14 1.30 169.35 5085.65 2236.33 -2074.69 3050.50 0.48 6241.37 1.22 181.08 5148.87 2234.96 -2074.57 3049.40 0.43 6304.76 1.36 168.02 5212.24 2233.54 -2074.43 3048.27 0.52 6368.08 1.40 169.88 5275.54 2232.05 -2074.14 3046.97 0.09 6425.88 1.49 184.39 5333.33 2230.61 -2074.07 3045.87 0.65 6490.13 1.52 195.61 5397.55 2228.95 -2074.36 3044.86 0.46 6551.63 1.85 189.54 5459.03 2227.19 -2074.75 3043.82 0.61 6614.65 0.81 170.71 5522.03 2225.75 -2074.84 3042.83 1.77 6675.95 0.55 181.37 5583.32 2225.03 -2074.78 3042.26 0.46 6738.79 0.68 173.67 5646.16 2224.35 -2074.75 3041.74 0.25 6800.86 0.70 182.38 5708.23 2223.61 -2074.72 3041.18 0.17 6862.81 0.79 163.35 5770.17 2222.82 -2074.61 3040.53 0.42 6925.24 0.74 175.70 5832.59 2222.00 -2074.46 3039.82 0.28 6986.89 1.05 173.54 5894.24 2221.04 -2074.37 3039.05 0.50 7047.67 1.29 182.32 5955.01 2219.81 -2074.33 3038.12 0.49 Hilcorp Alaska, LLC Kolatsa 1 29 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 7110.02 0.67 1.94 6017.35 2219.47 -2074.35 3037.89 3.15 7172.75 1.06 359.91 6080.07 2220.42 -2074.34 3038.58 0.62 7235.04 0.66 1.89 6142.36 2221.36 -2074.33 3039.26 0.64 7298.93 0.60 358.44 6206.24 2222.06 -2074.32 3039.77 0.11 7361.78 0.82 348.17 6269.09 2222.83 -2074.42 3040.41 0.40 7424.60 0.64 345.08 6331.91 2223.61 -2074.61 3041.10 0.30 7487.36 0.74 0.97 6394.66 2224.35 -2074.69 3041.70 0.34 7551.58 0.76 359.84 6458.87 2225.19 -2074.68 3042.31 0.04 7614.89 0.59 1.74 6522.18 2225.93 -2074.67 3042.85 0.27 7677.11 0.75 2.67 6584.39 2226.66 -2074.65 3043.36 0.26 7739.17 0.92 338.60 6646.45 2227.53 -2074.81 3044.11 0.63 7800.72 0.84 324.43 6707.99 2228.36 -2075.25 3045.02 0.38 7862.51 0.77 339.91 6769.78 2229.12 -2075.66 3045.86 0.37 7924.27 1.20 328.68 6831.53 2230.07 -2076.14 3046.88 0.76 7986.32 1.13 329.83 6893.56 2231.15 -2076.79 3048.11 0.12 8048.84 1.51 324.85 6956.06 2232.36 -2077.57 3049.53 0.64 8110.92 1.34 316.59 7018.12 2233.56 -2078.54 3051.07 0.43 8172.75 1.27 315.98 7079.94 2234.57 -2079.52 3052.48 0.12 8234.04 1.12 333.35 7141.22 2235.60 -2080.26 3053.73 0.64 8295.57 1.19 323.00 7202.73 2236.64 -2080.91 3054.95 0.36 8357.85 1.21 322.93 7265.01 2237.69 -2081.70 3056.25 0.03 8421.11 1.38 321.06 7328.24 2238.82 -2082.58 3057.68 0.28 8483.13 1.63 326.01 7390.24 2240.13 -2083.55 3059.30 0.45 8544.73 1.68 303.52 7451.82 2241.36 -2084.79 3061.04 1.05 8606.96 1.66 316.29 7514.03 2242.51 -2086.17 3062.83 0.60 8669.06 2.09 303.98 7576.09 2243.80 -2087.74 3064.83 0.95 8731.48 2.26 304.38 7638.46 2245.13 -2089.70 3067.14 0.27 8791.48 2.29 303.02 7698.42 2246.45 -2091.68 3069.46 0.10 8824.04 1.69 296.05 7730.96 2247.01 -2092.65 3070.53 1.99 **8866.00 1.69 296.05 7772.90 2247.56 -2093.76 3071.69 0.01 **Proj. Hilcorp Alaska, LLC Kolatsa 1 30 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drille d HRS AVE ROP (Ft/HR) CONDITION 1 9 7/8” Smith MSi519 JF4603 2x13, 3x15 134 1518 1384 10.2 135.7 2-6-BT-G-X-I-CT-TD 2 6 ¾” HDBS MM65D 12273689 6x10 1518 8866’ 7348’ 81.4 90.3 1-2-CT-G-X-I-NA-TD Hilcorp Alaska, LLC Kolatsa 1 31 4.3 Mud Record Contractor: Baroid Date Depth MW (ppg) VIS (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) MBT pH Cl (mg/l) Ca (mg/l) MD (ft) TVD (ft) Spud Mud 12/15/16 134’ 134’ 8.6 181 23 28 17/37/43 11.8 2/0 2.1 0/97.7 19 10.1 12/16/16 515’ 512’ 8.95 151 31 47 22/58/72 10.4 2/0 4.6 0/95.1 .6 27 9.3 650 12/17/16 1518’ 1366’ 9.05 53 40 4 6/15/25 9.0 2/0 5.4 0/94.4 .2 22 8.7 650 12/18/16 1518’ 1366’ 9.2 53 28 11 4/5/6 9.0 2/0 6.5 0/93.2 .2 20 8.3 650 12/19/16 1518’ 1366’ 9.3 52 27 11 3/4/7 9.0 2/0 7.2 0/92.6 .2 20 8.0 650 12/20/16 1518’ 1366’ 9.25 47 20 9 3/4/6 9.0 2/0 6.9 0/92.9 .2 20 8.1 650 6% KCl Polymer 12/21/16 1538’ 1378’ 9.0 51 8 15 7/9/11 6.2 1/0 2.4 0/94.9 9.6 32000 200 12/22/16 2974’ 2373’ 9.1 52 9 22 9/13/14 5.8 1/0 3.3 .4/93.9 .05 1 10.3 30000 260 12/23/16 4191’ 3236’ 9.15 43 8 18 8/10/13 5.8 1/2 3.6 0/93.8 .05 1.8 10.1 32000 360 12/24/16 5284’ 4202’ 9.05 46 9 19 8/11/14 6.0 1/2 3.0 0/94.6 .05 2.3 10.2 29000 200 12/25/16 5680’ 4592’ 9.15 42 7 19 8/10/13 6.4 1/2 3.9 0/93.8 .25 3.3 10.0 28000 160 12/26/16 6827’ 5734’ 9.2 56 13 20 8/14/18 4.9 1/2 3.9 0/93.4 .25 3.8 10.2 33000 120 12/27/16 7463’ 6372’ 9.25 48 12 21 7/14/18 4.8 1/2 4.1 0/93.4 .25 4.0 10.0 30000 80 12/28/16 8548’ 7456’ 9.3 49 13 20 7/12/16 4.4 1/2 4.7 0/92.8 .25 4.5 9.8 31000 40 12/29/16 8866’ 7772’ 9.3 63 15 24 7/13/18 4.0 1/2 4.8 0/92.8 .25 5.0 9.8 30000 80 12/30/16 8866’ 7772’ 9.5 53 14 22 7/13/16 4.4 1/2 5.6 0/92.2 0.25 5.0 10.0 27000 80 12/31/16 8866’ 7772’ 9.6 60 15 21 7/14/17 4.2 1/2 6.3 0/91.6 .25 5.0 9.6 26500 80 Abbreviations: MW = Mud Weight VIS = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded Hilcorp Alaska, LLC Kolatsa 1 32 4.4. Drilling Progress 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 12/14/201612/15/201612/16/201612/17/201612/18/201612/19/201612/20/201612/21/201612/22/201612/23/201612/24/201612/25/201612/26/201612/27/201612/28/201612/29/201612/30/201612/31/20161/1/20171/2/20179 7/8" 6 3/4" Hilcorp Alaska, LLC Kolatsa 1 33 5 DAILY REPORTS Hilcorp Alaska, LLC DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR R Pederson, R Wall DATE Dec 16, 2016 DEPTH 570 PRESENT OPERATION drilling TIME 23:59;59 YESTERDAY 120 24 HOUR FOOTAGE 450 CASING INFORMATION 16" @ 134' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 195.22 0.28 275.72 195.22 263.52 2.31 315.25 263.5 325.1 4.83 319.69 324.96 447.98 10.76 315.94 446.65 510.8 13.6 315.15 568.27 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#1 9 7/8" Smith MS1519 pdc JF4603 2x13, 3x15 112 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 380.5 @ 245 5.3 @ 317 158.1 238.7 FT/HR SURFACE TORQUE 6624 @ 293 0 @ 375 2614.5 5861.12 AMPS WEIGHT ON BIT 8 @ 555 0 @ 134 3.7 5.7 KLBS ROTARY RPM 54 @ 542 4 @ 426 22.7 53.8 RPM PUMP PRESSURE 1580 @ 555 433 @ 121 1159.7 1558.8 PSI DRILLING MUD REPORT DEPTH 515 MW 8.95 VIS 151 PV 31 YP 47 FL 10.4 Gels 22/58/72 CL- 650 FC 2 SOL 4.6 SD 0.6 OIL 0 MBL 27 pH 9.3 Ca+ - CCI MWD SUMMARY INTERVAL 112 TO TOOLS mwd, mudmotor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2 @ 556 0 @ 502 2.0 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 531 @ 556 162 @ 514 54.6 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ 0 AVG 0 PROPANE (C-3) @ @ 0 CURRENT 0 BUTANE (C-4) 0 @ @ 0.0 CURRENT BACKGROUND/AVG 2/0.2 PENTANE (C-5) 0 @ @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY sand, conglomerate, clay, claystone, and coal PRESENT LITHOLOGY 100% coal DAILY ACTIVITY SUMMARY p/u dp/racked back tagged bottom at 112’, total drill pipe racked back 35 stands, gather strap 9 joints of hwdp, p/u hwdp, rack back 4 stands, gather directional bha, install mwd sensors, gather/size 6.5” dc slips, collar clamp, pump through top drive, fill conductor, close manual IBOP, pressure test surface lines, leak between pumps, tighten union, retest 500 psi low back Kelly hose, p/u directional subs and bit, trouble shoot pason, p/u and m/u bha, drill 112’-245’, circulate hole clean, pooh f/245’ to bit, m/u bha, down load, load sources, m/u bha to 245’, drill 245’-291’, KOP 245’, rack back 1 stand hwdp, p/u jars/single hwdp, drill 291’-555’. CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR R. Pederson, R. Walls DATE Dec 17, 2016 DEPTH 1518 PRESENT OPERATION rih from flex collars TIME 23:59:59 YESTERDAY 570 24 HOUR FOOTAGE 948 CASING INFORMATION 16" @ 134' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1198.36 36.45 319.23 1132.14 1262.27 38.76 319.11 1182.77 1324.77 41.81 319.76 1230.44 1386.41 44.61 319.69 1275.36 1448.31 46.17 319.98 1318.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#1 9 7/8" Smith MSi519 JF4603 2x13, 3x15 112 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 335.4 @ 857 20.1 @ 1251 175.8 143.1 FT/HR SURFACE TORQUE 8803 @ 1396 0 @ 1362 5800.9 7993.8 AMPS WEIGHT ON BIT 18 @ 1309 0 @ 985 8.8 9.1 KLBS ROTARY RPM 81 @ 1482 1 @ 994 60.5 80.7 RPM PUMP PRESSURE 2242 @ 1512 1558 @ 570 1921.7 2178.8 PSI DRILLING MUD REPORT DEPTH 1518 MW 9.05 VIS 53 PV 40 YP 4 FL 9 Gels 6/15/25 CL- 650 FC 2 SOL 5.4 SD 0.2 OIL 0 MBL 22 pH 8.7 Ca+ - CCI MWD SUMMARY INTERVAL 112 TO TOOLS MWD, Modmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 127 @ 1278 1 @ 570 18.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 2u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 33827 @ 1279 421 @ 570 4838.6 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 20/15 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga claystone tuffaceous, sand, coal, carbonaceous shale PRESENT LITHOLOGY 30% tuffaceous claystone, 50% sand, 20% sandstone DAILY ACTIVITY SUMMARY drill 555-791, wipe new hole, drill 791 to 1518, pump high vis sweep 20% increase cuttings , wipe hole, pooh 1518 to 170, madpass every slide, monitor well, blow back kelley hose/standpipe, hole fill calc 10.18 bbls, meas. 30 bbl diff. 19+.82 bbls over,rig service, grease/inspect crown blocks, TD, DW, Brake linkage/drive line, chk all pins, keepers, change TD motor POP board, Tih from 170' at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa REPORT FOR R. Pederson, R Wall DATE Dec 18, 2016 DEPTH 1518 PRESENT OPERATION set packer TIME 23:59:59 YESTERDAY 1518 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @134 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1448.31 46.17 319.98 1318.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#1 9 7/8" Smith MSi519 PDC JF 4603 2x13, 3x15 112 1518 1406 10.2 2,6,BT,G,X,I,CT, TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG 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 SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 112 TO 1518 TOOLS MWD, Mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 9.6 @ 0 @ 0.5 TRIP GAS 2u CUTTING GAS @ @ WIPER GAS 8u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0.3/0.5 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga claystone tuffaceous, sand, coal, carbonaceous shale PRESENT LITHOLOGY 30% tuffaceous claystone, 50% sand, 20% sandstone DAILY ACTIVITY SUMMARY : rih to bottom, circ bottoms up, pooh, lay down bha and bit, download memory, pull wear bushing, dummy hangar joint, clean rig floor, r.u csg equip, run 7.625 csg land out at 1509.33 200 gpmn press = 57, circ while r/u cement equip/crew, shut down pumps, break off top drive, circ swedge, blow back kelley hose, r/u cement bowl head lines and manifold, pjsm with slb cement crew, circ on scg while batching in cement, shut down rig pump, line up cementers, pump 5 bbl water, pt lines 1600/3800, line up manifold, pump 23 blls 10 ppg mudpush at 5 bpm, drop btm plug slb pump 89.6 bbl 12 ppg lead at 4.8 bpm, 27.4 bll 15.4 ppg tail, drop top plug, dispace 67 bbl, 9.2 ppg mud at 4.8 bpm, fcp 500 psi, bumped plug 500 psi over at 2215 hrs, held 3 min, bled back 0.5 bbl, floats held, wash up/blow back cement lines, blowback standpipe/displacement feed lines, r.dn cementers, such out cellar, casing bailsds, slb left at 24 hrs, back out landing joint, wash out top of casing hanger, make up packer to landing joing, set packer CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa REPORT FOR R. Pederson, R. Walls DATE Dec 19, 2016 DEPTH 1518 PRESENT OPERATION nipple up TIME 23:59:59 YESTERDAY 1518 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @134' 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1448.31 46.17 319.98 1318.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#1 9 7/8"" Smith MSi519 pdc JF 4603 2x13, 3x15 112 1518 1406 10.2 2,6,BT,G,X,I,CT, TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1518 MW 9.2 VIS 53 PV 28 YP 11 FL 9 Gels 4/5/6 CL- 6.5 FC 2 SOL 6.5 SD 0.2 OIL 0 MBL 20 pH 8.3 Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY 30% tuffaceous claystone, 50% sand, 20% sandstone DAILY ACTIVITY SUMMARY back out landing joint, wash out top of casing hanger, make up packer to landing joing, set packer , tighten all lock downs, back out of packer, lay down running tool and landing joint, nipple down diverter, clean cellar, nipple up well head, pressure test viod low 500 high 1500 for 15 min, stage bop cratle, set crain, install spacer spool, fly in bops, change studs on bottom of stack, move cradle load out diverter equipment, install inside kill inside choke, hyd choke and kill, continue nippling up. CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR R. Pederson, R. Wall DATE Dec 20, 2016 DEPTH 1518 PRESENT OPERATION p/u dp TIME 23:59:59 YESTERDAY 1518 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 134 4 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1448.31 46.17 319.98 1318.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#1 9 7/8" Smith MSi519 pdc JF4603 2x13, 3x15 112 1518 1406 10.2 2,6,BT,G,X,I,CT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1518 MW 9.3 VIS 52 PV 27 YP 11 FL 9 Gels 7/9/10 CL- 650 FC 2 SOL 7.2 SD 0.2 OIL 0 MBL 20 pH 8 Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY 30% tuffaceous claystone, 50% sand, 20% sandstone DAILY ACTIVITY SUMMARY Nipple up bop, test bop, test 7 5/8" casing to 3500 for 30 min, install 9" id wear bushing, repair bell nipple and install, strap and pick up drill pipe CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa REPORT FOR Clint Montague, Robert Wall DATE Dec 21, 2016 DEPTH 1538 PRESENT OPERATION transfer mud into active TIME 23:59:59 YESTERDAY 1518 24 HOUR FOOTAGE 20 CASING INFORMATION 16" @134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#2 6 3/4" HDBS MM65D PDC 12273689 6x10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 157.5 @ 1521 21.1 @ 1537 95.1 21.1 FT/HR SURFACE TORQUE 5036 @ 1523 4792 @ 1521 5167.3 4859.1 AMPS WEIGHT ON BIT 3 @ 1523 0 @ 1519 2.5 1.5 KLBS ROTARY RPM 29 @ 1520 28 @ 1533 30.7 29.2 RPM PUMP PRESSURE 1528 @ 1523 1402 @ 1519 1560.3 1442.7 PSI DRILLING MUD REPORT DEPTH 1518 MW 9 VIS 51 PV 7 YP 16 FL 6.2 Gels 7/11/13 CL- 32k FC 1 SOL 2.3 SD - OIL 0 MBL - pH 9 Ca+ 200 CCI 0.25 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, Mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 @ 1524 0.8 @ 1520 1.1 TRIP GAS 3u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 226 @ 1536 162 @ 1521 204.0 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1/1 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY 10% tuffaceous claystone, 80% sand, 10% sandstone DAILY ACTIVITY SUMMARY continue pick up drill pipe for 115 total stands in derrick, stage, strap and tally BHA, make up BHA to 120, worm up tools down load, pulse test, s/m radio active sources ins sources, continue RIH with BHA, single in hole 590-1117, circulate bottoms up, single in 1117-1356, from derrick to 1403, tag cement, drill out float collar at 1422 and shoe at 1507, clean out to 1518, drill to 1538, circulate bottoms up, pull back into casing and perform a fit test to 14.3 ppg EMW with 9.2 ppg mud, applied pressure , pjsm for displacement, displace well with KCL mud, clean shaker tank, change shaker screes to 140 mesh, transfer mud into active. CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague, R. Walls DATE Dec 22, 2016 DEPTH 2984 PRESENT OPERATION Drilling ahead TIME 23:59:59 YESTERDAY 1538 24 HOUR FOOTAGE 1446 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2944.11 46.89 320.45 2352.84 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB #2 6 3/4" HDBS MM65D PDC 12273689 6X10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 231.9 @ 1879 12.4 @ 1560 131.8 110.4 FT/HR SURFACE TORQUE 7741 @ 2491 0 @ 2680 5740.0 7237.4 AMPS WEIGHT ON BIT 8 @ 1559 0 @ 1627 3.4 3.5 KLBS ROTARY RPM 82 @ 2493 8 @ 1618 65.1 81.16000 RPM PUMP PRESSURE 1717 @ 2881 897 @ 1538 1393.8 1669.0 PSI DRILLING MUD REPORT DEPTH 1538 MW 9 VIS 51 PV 8 YP 15 FL 6.2 Gels 7/9/11 CL- 32k FC 1 SOL 2.4 SD - OIL 0 MBL - pH 9.6 Ca+ 200 CCI 0.25 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 216 @ 2519 2 @ 1539 42.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 33u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 55446 @ 2520 263 @ 1539.00000 10702.5 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 7/6 PENTANE (C-5) @ @ HYDROCARBON SHOWS Gas INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION a.1660-1678 b.2495-2530 a. sand, tuffaceous claystone b. sand tuffaceous claystone a. 187u b. 216u Both methane shows in sand. LITHOLOGY Beluga PRESENT LITHOLOGY 100% sand DAILY ACTIVITY SUMMARY drill 1538-2482, circulate bottoms up, pump 20 bbl high vis sweep, wipe hole to shoe, no issues, hole took 1.8 over calc fill, service rig, grease drawworks blocks, crown, check brakes, I.R. check bear traps, rih 1487-2482, drill 2482-2984. CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague, R. Wall DATE Dec 23, 2016 DEPTH 4228 PRESENT OPERATION drilling ahead TIME 23:59:59 YESTERDAY 2984 24 HOUR FOOTAGE 1244 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4186.92 38.76 318.2 3232.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#2 6 3/4" HDBS MM65D PDC 12273689 6x10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 185.8 @ 3678. 7.1 @ 3489 120.2 124.0 FT/HR SURFACE TORQUE 9269 @ 4185 0 @ 3923 6669.1 8839.2 AMPS WEIGHT ON BIT 9 @ 4094 0 @ 3359 4.0 5.6 KLBS ROTARY RPM 81 @ 3019 5 @ 3673 67.5 79.4 RPM PUMP PRESSURE 1857 @ 3739 1427 @ 4165 1695.6 1645.8 PSI DRILLING MUD REPORT DEPTH 2974 MW 9.1 VIS 52 PV 9 YP 22 FL 5.8 Gels 9/13/14 CL- 30k FC 1 SOL 3.3 SD 0.05 OIL 0 MBL 1 pH 10.3 Ca+ 260 CCI 0.85 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, mudlmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 360 @ 3415 2 @ 3680 49.4 TRIP GAS CUTTING GAS @ @ WIPER GAS 23u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 88648 @ 3415.00000 801 @ 3680.00000 12428.6 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 13/6 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga PRESENT LITHOLOGY 30% tuffaceous claystone, 10% coal, 60% sand DAILY ACTIVITY SUMMARY drill 2984-3481; pump sweep circulate 20 bbls high vis 20% increase cuttings, pooh 3481-2552, tight spots at 2819-2809 25k, 2764-2760 25k, 2708-2678 25km 2579 30k, on elevators 2552-2390, rig service, grease drawworks, check brakes, grease top drive, reset c.o.m., rih 2390- 3481, no issues, drill 3481-3851, pump 20 bbl high vis sweep, drill 3851-4228. CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague, R. Wall DATE Dec 24, 2016 DEPTH 5284 PRESENT OPERATION drilling ahead TIME 23:59:59 YESTERDAY 4228 24 HOUR FOOTAGE 1056 CASING INFORMATION 16 " @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5246.13 16.52 316.75 4166.02 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#2 6 3/4" HDBS MM65D PDC 12273689 6x10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 221.1 @ 4497 4.7 @ 5174 121.5 148.34 FT/HR SURFACE TORQUE 11021 @ 4936 0 @ 5226 7552.0 10220.2 AMPS WEIGHT ON BIT 8 @ 4407 0 @ 4292 4.6 3.3 KLBS ROTARY RPM 81 @ 4314 1 @ 4727 58.9 78.4 RPM PUMP PRESSURE 2328 @ 4665 1386 @ 4909 1746.5 1837.1 PSI DRILLING MUD REPORT DEPTH 4191 MW 9.15 VIS 43 PV 8 YP 18 FL 5.8 Gels 8/10/13 CL- 32k FC 1/2 SOL 3.6 SD 0.05 OIL 0 MBL 1.8 pH 10.1 Ca+ 360 CCI 1.2 MWD SUMMARY INTERVAL 5118 TO TOOLS MWD, mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 337 @ 5279.00000 3 @ 4727.00000 49.0 TRIP GAS CUTTING GAS 0 @ @ WIPER GAS 43u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 82919 @ 5279.00000 802 @ 4727.00000 12272.4 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 7 /4 PENTANE (C-5) @ @ HYDROCARBON SHOWS gas INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION a. 4380-4405 b. 5100-5130 c. 5260-5285 a.sand, tuffaceous claystone,sandstone b and c. tuffaceous claystone/siltstone, sand, sandstone and tuffaceous sandstone a. 240u b. 184u c. 339u a. v fn-u med b. l v fn-l med c. v fn-med LITHOLOGY Tyonek PRESENT LITHOLOGY 40% tuffaceous claystone, 10% tuffaceous silstone, 30% sand, 10% sandstone, 10% tuffaceous sandstone DAILY ACTIVITY SUMMARY drill 4228-4476, pump sweep, circulate hole clean, wipe/pooh on elevators, 4476-3416, tight 3763 and 3653 30k over, work threw once, hole fill 1.8 bbls over theo, rih 3416-4476 no issues, drill 4476-5284 CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague, R. Wall DATE Dec 25, 2016 DEPTH 5718 PRESENT OPERATION drilling ahead TIME 23:59:59 YESTERDAY 5284 24 HOUR FOOTAGE 434 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5680.12 8.73 316.35 4589.38 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#2 6 3/4" HDBS MM65D PDC 12273689 6x10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 197.4 @ 5623 5.3 @ 5596 125.3 136.9 FT/HR SURFACE TORQUE 11671 @ 5702 0 @ 5357 8706.5 11171.1 AMPS WEIGHT ON BIT 8 @ 5567 0 @ 5351 5.6 6.9 KLBS ROTARY RPM 79 @ 5487 0 @ 5292 61.8 78.0 RPM PUMP PRESSURE 1974 @ 5704 1442 @ 5496 1815.6 1946.3 PSI DRILLING MUD REPORT DEPTH 5384 MW 9.05 VIS 46 PV 9 YP 19 FL 6 Gels 8/11/14 CL- 29k FC 1/2 SOL 3 SD 0.05 OIL 0 MBL 2.3 pH 10.2 Ca+ 200 CCI 1 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, Mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 271 @ 5340 9 @ 5416 74.6 TRIP GAS CUTTING GAS @ @ 0.0 WIPER GAS 49u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 66970 @ 5341 1724 @ 5416 19682.8 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 6/5 PENTANE (C-5) @ @ HYDROCARBON SHOWS gas INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5335-5410 tuffaceous sand, sandstone, interbeded coal at 5350 271 very fine to medium lower, ash matrix, trace hard cement. LITHOLOGY Tyonek PRESENT LITHOLOGY 20% tuffaceous claystone, 60% tuffaceous siltstone, 20% sandstone DAILY ACTIVITY SUMMARY drill 5281-5470, pump sweep, circ hole clean, wipe hole, wie 5470-4786, 30k over at 4815, multiple tight spots 4815-4670, ream tight spots 4622-4507 and 3311-2346, pump high vis sweep, wipe 2346-1490 on elev, grease drawworks, top drive, blocks and I.R., rih 1496-5348, no issues, hole took 2.3 bbl under calc displacement, ream last stand, level derrick, tagged fill at 5461m drukk 5470-5718 CANRIG PERSONNEL ON BOARD 4 DAILY COST 3945 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague, R. Wall DATE Dec 26, 2016 DEPTH 6854 PRESENT OPERATION drilling TIME 23:59:59 YESTERDAY 5718 24 HOUR FOOTAGE 1136 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6800.86' 0.7 182.38 5708.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#2 6 3/4" HDBS MM65D pdc 12273689 6x10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 190.8 @ 6839 3.2 @ 5719 104.5 144.9 FT/HR SURFACE TORQUE 13640 @ 6471 0 @ 5918 10901.6 13309.7 AMPS WEIGHT ON BIT 10 @ 6617 0 @ 5918 5.6 5.8 KLBS ROTARY RPM 79 @ 6052 2 @ 5793 67.1 75.5 RPM PUMP PRESSURE 2137 @ 6853 1588 @ 5877 1906.0 2135.9 PSI DRILLING MUD REPORT DEPTH 5680 MW 9.15 VIS 42 PV 7 YP 19 FL 6.4 Gels 8/10/13 CL- 28k FC 1/2 SOL 3.9 SD 0.25 OIL 0 MBL 3.3 pH 10 Ca+ 160 CCI 0.8 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 573 @ 5814.00000 3 @ 6262.00000 59.5 TRIP GAS CUTTING GAS 0 @ @ WIPER GAS 49u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 154974 @ 5813.00000 568 @ 5946.00000 17099.6 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 7/6 PENTANE (C-5) @ @ HYDROCARBON SHOWS gas INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION a. 5780-5825 b. 6295-6335 c. 6405- 6485 sand, tuffaceous sandstone, sand. a.573u b. 460u c. 288u a. crs - v fn to v fn - med loose sand, sandstone bones. b. v fn-v crs c. v fn-med LITHOLOGY Tyonek PRESENT LITHOLOGY Sandstone 40% Tuffaceus Claystone 20%, Tuffaceous Siltstone 40% DAILY ACTIVITY SUMMARY drill 5718-6466, pump sweep, wipe 6466-5441, drill 6466-6854 CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa REPORT FOR C. Montague, A. Dorr DATE Dec 27, 2016 DEPTH 7527 PRESENT OPERATION drilling ahead TIME 23:59:59 YESTERDAY 6854 24 HOUR FOOTAGE 673 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7487.36 0.74 0.97 6394.66 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB #2 6 3/4" HDBS MM65D pdc 12273689 6x10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 189.8 @ 6871 1.4 @ 7349 95.3 75.8 FT/HR SURFACE TORQUE 14732 @ 7473 0 @ 7100 13165.4 14091.2 AMPS WEIGHT ON BIT 10 @ 7372 0 @ 7127 6.3 7.8 KLBS ROTARY RPM 77 @ 7113 8 @ 7090 72.0 74.8 RPM PUMP PRESSURE 2336 @ 7406 1775 @ 6966 2129.9 2131.1 PSI DRILLING MUD REPORT DEPTH 7463 MW 9.25 VIS 48 PV 12 YP 21 FL 4.8 Gels 7/14/18 CL- 30k FC 1/2 SOL 4.1 SD 0.25 OIL 0 MBL 4 pH 10 Ca+ 80 CCI 0.8 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, Mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 213 @ 7490 4 @ 7007 32.8 TRIP GAS CUTTING GAS @ @ WIPER GAS 20u, 3268u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 49866 @ 7392.00000 966 @ 7013.00000 9306.9 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 11/9 PENTANE (C-5) @ @ HYDROCARBON SHOWS gas-methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION a. 6854-6864 b. 7151-7170 c. 7354- 7400 Sand, conglomerate, tuffaceous sandstone, sandstone a. 129u b. 100u c. 120u a. conglomerate gran - v fn b. v fn - med c. v fn - fn. LITHOLOGY Tyonek PRESENT LITHOLOGY 10% carbonaceous shale, 60% claystone, 20% tuffaceous siltstone, 10% sandstone DAILY ACTIVITY SUMMARY drill 6864-6970, work on top drive, drill 6970-7027, circ btms up, pump hi vis swwep, pull to 6900, circ at 48 spm, 753u max, work on top drive, rih to bottom, 20u wiper gas, drill 7027-7463, circ btms up, pump higw vis sweep, wipe to 6464, wiper gas 3268u, drill 7463-7527 CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague, A. Dorr DATE Dec 28, 2016 DEPTH 8619 PRESENT OPERATION drilling ahead TIME 23:59:59 YESTERDAY 7527 24 HOUR FOOTAGE 1092 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8544.73 1.68 303.52 2241.36 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB #2 6 3/4" HDBS MM65D 12273689 6x10 1518 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 186.0 @ 8473 7.7 @ 8526 81.6 100.2 FT/HR SURFACE TORQUE 16573 @ 8591 219 @ 8347 15015.3 16336.8 AMPS WEIGHT ON BIT 12 @ 8047 0 @ 8528 8.3 5.3 KLBS ROTARY RPM 87 @ 8346 2 @ 8566 73.6 72.7 RPM PUMP PRESSURE 2568 @ 8368 1977 @ 7964 2284.1 2382.6 PSI DRILLING MUD REPORT DEPTH 8548 MW 9.3 VIS 49 PV 13 YP 20 FL 4.4 Gels 7/12/16 CL- 31k FC 1/2 SOL 4.7 SD 0.25 OIL 0 MBL 4.5 pH 9.8 Ca+ 40 CCI 0.6 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, Mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1018 @ 7596 4 @ 8344 58.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 213604 @ 7596 749 @ 8344 13276.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 8619 0 @ 8619 0.0 AVG 0 PROPANE (C-3) 60 @ 7601 31 @ 7829 1.0 CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 9/8 PENTANE (C-5) @ @ HYDROCARBON SHOWS gas INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION a. 7566-7615 b. 7820-7832 c. 8383-8438 d. 8570-8576 sand, sandstone, conglomerate, tuffaceous sandstone a. 1018u C3,C1 b. 537u C3,C1 c. 233u C1 d. 105u C1 a. v fn-crs, v fn-med b. carbonaceous sandstone v fn c. v fn-crs d. conglomerate v fn - upr v crs. LITHOLOGY Tyonek PRESENT LITHOLOGY 50% sand, 20% sandstone, 30% tuffaceous sandstone DAILY ACTIVITY SUMMARY drill 7527-8334, replace top drive hose, drill 8334-8347, rack back stand and repair top drive, drill 8347-8619 CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague / A. Dorr DATE Dec 29, 2016 DEPTH 8866 PRESENT OPERATION rih TIME 23:59:59 YESTERDAY 8619 24 HOUR FOOTAGE 247 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8666 1.69 296.05 7772.9 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB #2 6 3/4" HDBS MM65D pdc 12273689 6x10 1518 7348 81.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 140.8 @ 8802 3.5 @ 8681 69.1 75.6 FT/HR SURFACE TORQUE 17073 @ 8680 1160 @ 8807 15404.2 16798.6 AMPS WEIGHT ON BIT 10 @ 8830 0 @ 8816 7.0 8.6 KLBS ROTARY RPM 75 @ 8827 3 @ 8807 68.2 71.2 RPM PUMP PRESSURE 2489 @ 8860 2132 @ 8806 2410.6 2477.8 PSI DRILLING MUD REPORT DEPTH 8866 MW 9.3 VIS 63 PV 15 YP 24 FL 4 Gels 7/13/18 CL- 30k FC 1/2 SOL 4.8 SD 0.25 OIL 0 MBL 5 pH 9.8 Ca+ 80 CCI 0.9 MWD SUMMARY INTERVAL 1518 TO TOOLS MWD, mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 197 @ 8622 10 @ 8742 46.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 45680 @ 8623 2194 @ 8682 10530.8 CONNECTION GAS HIGH 0 ETHANE (C-2) @ 0 @ AVG 0 PROPANE (C-3) @ 0 @ CURRENT 0 BUTANE (C-4) @ 0 @ CURRENT BACKGROUND/AVG 14/11 PENTANE (C-5) @ 0 @ HYDROCARBON SHOWS gas INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8618-8630 sand, sandstone, conglomerae 197u v fn - v crs LITHOLOGY Tyonek PRESENT LITHOLOGY 60% tuffaceous siltstone, 30% sandstone, 10% tuffaceous sandstone DAILY ACTIVITY SUMMARY drill 8619-8866, pump sweep, circ hole clean, wipe to shoe, (spot ream tight spots 30-40k over @7638, 5395, 5331 and 5020, back ream 4900-4300, 267u max, pump hi vis sweep, circ hole clean, 20u max pooh 4300-1494,) service rig, rih 1494-5200 CANRIG PERSONNEL ON BOARD 4 DAILY COST 3145 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague / A. Dorr DATE Dec 30, 2016 DEPTH 8866 PRESENT OPERATION pooh l/d dp TIME 23:59:59 YESTERDAY 8866 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#2 6 3/4" HDBS MM65 pdc 6x10 6x10 1518 8866 7348 81.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8866 MW 9.5 VIS 53 PV 14 YP 22 FL 4.4 Gels 7/13/16 CL- 27k FC 1/2 SOL 5.6 SD 0.25 OIL 0 MBL 5 pH 10 Ca+ 80 CCI 0.8 MWD SUMMARY INTERVAL 1518 TO 8866 TOOLS MWD, mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2014 @ 11 @ 200 TRIP GAS CUTTING GAS @ @ WIPER GAS 2014u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 11/20 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY 60% tuffaceous siltstone, 30% sandstone, 10% tuffaceous siltstone DAILY ACTIVITY SUMMARY rih, circ btms up 6469, max gas 2014u, rih, 8361, tight pull to 8214, circ btms up max gas 1916u, rih 8214-83500, wash ream 8350-8450, rih 8450-8866, pump sweep, circ wt up to 9.5 ppg, max gas 286u, pooh to 8048 l/d dp, condition mud and circ, max gas 44u, rih 8048-8432, pooh l/d dp to 1110 CANRIG PERSONNEL ON BOARD 2 DAILY COST 2105 REPORT BY Russell Wardner Hilcorp Alaska, LLC Ninilchik Field DAILY WELLSITE REPORT Kalotsa #1 REPORT FOR C. Montague / A. Dorr DATE Dec 31, 2016 DEPTH 8866 PRESENT OPERATION rih 4 1/2" casing from 6665 TIME 23:59:59 YESTERDAY 8866 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 134 7 5/8" @ 1509 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB#2 6 3/4" HDBS MM65 pdc 6x10 6x10 1518 8866 7348 81.4 1,2,CT,G,X,I,NA, TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8866 MW 9.5 VIS 53 PV 14 YP 22 FL 4.4 Gels 7/13/16 CL- 27k FC 1/2 SOL 5.6 SD 0.25 OIL 0 MBL 5 pH 10 Ca+ 80 CCI 0.8 MWD SUMMARY INTERVAL 1518 TO 8866 TOOLS MWD, mudmotor, LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 104 @ 2 @ 40 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3/2 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY 60% tuffaceous siltstone, 30% sandstone, 10% tuffaceous siltstone DAILY ACTIVITY SUMMARY l/d drill pipe, and bha, break and l/d bit, pulled wear ring and dummy ran hanger, r/u weathorford csg equip, rih w/4 1/2" csg, circ btms up @ shoe, 3790 and 6428 with max gases 1u, 28u and 104u, rih csg from 6665. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2105 REPORT BY Russell Wardner