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Home My WebLink About217-063CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Tabitha Timothy To:Brooks, James S (OGC) Subject:Kalotsa 3 & 4 Question Date:Thursday, December 18, 2025 11:45:02 AM Attachments:image001.pngimage002.png Good Afternoon, It was brought to my attention earlier this year that two wells had API numbers swapped between the two of them in our previous accounting system. It was found when we changed systems, but unfortunately the production was reported to AOGCC incorrectly up until 05/2025. These wells both came online in 2017. The API is correct here in Data Miner but in our system was flipped and therefore in the Data Miner Production tab the 07/2017-04/2025 reports that were loaded based on our EDIs have production volumes flipped. I am trying to determine the best way to correct this. Is there a way on your end that you can switch the production reports for these two wells? Or will I need to submit a new Field 562 Report with all the wells in Ninilchik for this 8 year period. Thank you, Tabitha Timothy Production Accounting Lead Hilcorp – Alaska Direct: 713.289.2889 Cell: 832.702.0982 2025 Customer Service Goal: In a world full of 2’s…BE A 3! The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediatelynotify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,221 feet See Schematic feet true vertical 7,958 feet 9,061(fish)feet Effective Depth measured 7,625 feet 1,298 feet true vertical 6,395 feet 1,242 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A 1,298 MD Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr 1,242 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 6,890psi 8,430psi 1,491'1,387' Burst Collapse 4,790psi Production Liner 9,213' Casing Structural 7,950'9,213' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,491' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-063 50-133-20665-00-00 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: C061505 (SHL) / ADL384372 (BHL) Ninilchik / Beluga-Tyonek Gas Pool NINU Kalotsa 4 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 76 Size 120' 0 791709 0 390 45 Scott Warner, Operations Engineer 325-064 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1603 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 10:01 am, Mar 17, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.03.14 16:59:06 - 08'00' Noel Nocas (4361) DSR-3/25/25BJM 5/2/25 RBDMS JSB 032625 Page 1/1 Well Name: NINU Kalotsa 04 Report Printed: 2/26/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:2/6/2025 End Date: Report Number 1 Report Start Date 2/15/2025 Report End Date 2/15/2025 Last 24hr Summary Drift tubing w/ 3.75'' g-ring clean out from 2260' to 2489'-5276' to 5290' tag fill @ 7548' w/ 2 7/8''x20' dummy guns PTW/PJSM. FTP 53 psi. RU Pollard Slickline. PT lubricator 250 psi low / 2500 psi high - good test. RIH w/ 3.75" GR and tag @ 2,489' RKB. RIH w/ 2 1/2" bailer and tag @ 7,552' RKB. RIH w/ 3.75" GR and tag @ 5,290' RKB. RIH w/ 2 7/8" x 20' dummy gun and tag @ 7,548' RKB. Secure well, RD Pollard. Report Number 2 Report Start Date 2/22/2025 Report End Date 2/22/2025 Last 24hr Summary PTW/PJSM. 220 psi SITP. MIRU YJ E-line. PT lubricator to 2500 psi - good test. RIH w/ GPT and find fluid level ~ 6,555'. RIH w/ 20' x 2 3/4" 6 SPF 60 DEG guns and perf TY_53 (7,485’ – 7,505’). Secure well, SDFN, flow well. Report Number 3 Report Start Date 2/23/2025 Report End Date 2/23/2025 Last 24hr Summary PTW/PJSM. 215 psi SITP. RU YJ E-line. RIH w/ 10'x6'x6' x 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_42 (6,945’ – 6,955’), TY_37 (6,764’ – 6,770’), and TY_18 (6,524’ – 6,530’). RIH w/ 18' x 2 3/4" 6 SPF 60 DEG guns and perf TY_16 (6,350’ – 6,368’). RIH w/ 6'x10' x 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_14 (6,181’ – 6,187’) and TY_10 (5,577’ – 5,587’). RIH w/ 14'x10' x 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_8 Lower (5,472’ – 5,486’) and TY_8 Upper (5,458’ – 5,468’). RIH w/ 6'x6'x6' x 2 3/8" 5 SPF 60 DEG guns on switch and perf TY_7 (5,382’ – 5,388’), TY_6 Lower (5,295’ – 5,301’), and TY_6 Upper (5,285’ – 5,291’). Secure well, SDFN, flow well. Report Number 4 Report Start Date 2/24/2025 Report End Date 2/24/2025 Last 24hr Summary PTW/PJSM. 250 psi SITP. RU YJ E-line. RIH w/ 10'x14' x 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_5B (5,177’ – 5,187’) and TY_5A (5,138’ – 5,152’). RIH w/ 6'x6' x 2 3/8" 5 SPF 60 DEG guns on switch and perf TY_5 (5,099’ – 5,105’) and TY_3 Lower (4,988’ – 4,994’). RIH w/ 16' x 2 3/4" 6 SPF 60 DEG guns and perf TY_3 Upper (4,958’ – 4,974’). Secure well, RDMO YJ E-line, Flow well. Field: Ninilchik Sundry #: 325-064 State: Alaska Rig/Service:Permit to Drill (PTD) #:217-063Permit to Drill (PTD) #:217-063 Wellbore API/UWI:50-133-20665-00-00 Updated by DMA 03-03-25 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 7,637’ / PBTVD = 6,406’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120' 7-5/8"Surf Csg 29.7 L-80 BTC 6.875”Surf 1,491’ 4-1/2"Prod Csg 12.6 L-80 DWC/C HT 3.958”Surf 9,213’ JEWELRY DETAIL No.Depth ID OD Item 1 1,298’3.958”6.875”Baker Swell Packer 2 7,637’4.500”CIBP (8-31-2022) w/ 25’ cmt (TOC 7,612’ 9/28/23) 3 8,995’4.500”CIBP 4 9,054’4.500”CIBP w/ 5’ of cement 02/01/18 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2” 6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows Ratty TOC = ~840’ MD, with good TOC starting at ~1700’ PERFORATION DETAIL Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt Date Status TY3 4,958'4,974'3,803'3,818'16'2/24/25 Open TY3 4,988'4,994'3,831'3,836'6'2/24/25 Open TY5 5,099'5,105'3,934'3,939'6'2/24/25 Open TY5A 5,138'5,152'3,971'3,984'14'2/24/25 Open TY5B 5,177'5,187'4,008'4,017'10'2/24/25 Open T6 5,222'5,249'4,050'4,076'27'9/29/23 Open T6 5,260'5,277'4,087'4,103'17'9/29/23 Open TY6 5,285'5,291'4,111'4,116'6'2/23/25 Open TY6 5,295'5,301'4,120'4,126'6'2/23/25 Open T7 5,355'5,363'4,178'4,186'8'9/29/23 Open T7 5,366'5,376'4,189'4,198'10'9/29/23 Open TY7 5,382'5,388'4,204'4,210'6'2/23/25 Open T7 5,407'5,417'4,228'4,238'10'9/29/23 Open T7 5,421'5,429'4,242'4,250'7'9/29/23 Open T8 5,443'5,447'4,263'4,267'4'9/29/23 Open T8 5,450'5,458'4,270'4,278'8'9/29/23 Open TY8 5,458'5,468'4,278'4,287'10'2/23/25 Open TY8 5,472'5,486'4,291'4,305'14'2/23/25 Open T9A 5,535'5,547'4,353'4,364'12'9/29/23 Open TY10 5,577'5,587'4,394'4,403'10'2/23/25 Open T10A 5,613'5,623'4,429'4,438'10'9/28/23 Open T10A 5,641'5,648'4,456'4,463'7'9/28/23 Open T10B 5,653'5,664'4,468'4,478'11'9/28/23 Open T11U 5,690’5,694’4,504’4,508’4'09/06/22 Open T11M 5,696’5,702’4,509’4,515’6'09/06/22 Open T11L 5,716’5,722’4,529’4,535’6'09/06/22 Open T11A 5,800’5,804’4,611’4,614’4'09/06/22 Open T12 5,888’5,905’4,696’4,713’17'09/06/22 Open TY12 5,920'5,926'4,728'4,733'6'2/23/25 Open TY14 6,181'6,187'4,983'4,989'6'2/23/25 Open TY16 6,350'6,368'5,148'5,166'18'2/23/25 Open T16A 6,332’6,350’5,131’5,148’18'09/01/22 Open T17U 6,387’6,407’5,185’5,204’20'09/01/22 Open T17L 6,414’6,434’5,211’5,231’20'09/01/22 Open T18U 6,509’6,520’5,304’5,315’11'08/31/22 Open TY18 6,524'6,530'5,319'5,325'6'2/23/25 Open T18M 6,537’6,547’5,332’5,341’10'08/31/22 Open T18L 6,550’6,560’5,344’5,354’10'08/31/22 Open TY37 6,764'6,770'5,554'5,560'6'2/23/25 Open T37U 6,799’6,823’5,589’5,612’24'08/31/22 Open T37L 6,816’6,828’5,605’5,617’12'08/31/22 Open TY42 6,945'6,955'5,732'5,741'10'2/23/25 Open TY53 7,485'7,505'6,258'6,277'20'2/22/25 Open PERFORATION DETAIL continued on following page T146 T140 - T142 4 TOF @ 9,061’ 01/31/18 Fish Description Lost in Hole 8890’ Slickline TS: ~25’ OAL, 3.5” OD: LIB 6/20/22 8920’ E-line TS: 32.5’ OAL, 3.60”OD: GR, JB, CCL, 1-7/16 RS, 1in FN 6/19/22 9061’ Weatherford WRP w/ catcher sub, wire and LIB 1/31/18 T115 T80 T65 3 T83 – T100 T69 T73 T118 T11 T12 T16 T17 T18 T37 2 T6-T8 T10 Updated by DMA 03-03-25 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PERFORATION DETAIL continued from previous page PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Date Status T65 7,687’ 7,707’ 6,455’ 6,475’ 20’ 08/31/22 Isolated T65L 7,707’ 7,734’ 6,475’ 6,501’ 27’ 08/31/22 Isolated T69 7,824’ 7,844’ 6,589’ 6,608’ 20’ 08/31/22 Isolated T73 7,918’ 7,927’ 6,680’ 6,689’ 9’ 08/31/22 Isolated T80 7,967’ 7,970’ 6,728’ 6,731’ 3’ 08/31/22 Isolated T80 7,984’ 7,995’ 6,745’ 6,755’ 11’ 08/31/22 Isolated T83 8,039’ 8,052’ 6,799’ 6,811’ 13’ 08/31/22 Isolated T87 8,152’ 8,162’ 6,909’ 6,919’ 10’ 08/31/22 Isolated T90U 8,187’ 8,198’ 6,943’ 6,954’ 11’ 08/31/22 Isolated T90M 8,235’ 8,241’ 6,990’ 6,996’ 6’ 08/31/22 Isolated T90L 8,266’ 8,281’ 7,020’ 7,035’ 15’ 08/31/22 Isolated T100 8,374’ 8,389’ 7,126’ 7,140’ 15’ 08/31/22 Isolated T115U 8,462’ 8,472’ 7,211’ 7,221’ 10’ 08/31/22 Isolated T115L 8,475’ 8,487’ 7,224’ 7,236’ 12’ 08/31/22 Isolated T115 8,489’ 8,504’ 7,238’ 7,252’ 15’ 08/31/22 Isolated T115 8,570’ 8,581’ 7,317’ 7,328’ 11’ 08/31/22 Isolated T115 8,583’ 8,596’ 7,330’ 7,343’ 13’ 08/31/22 Isolated T118 8,612’ 8,621’ 7,358’ 7,367’ 9’ 08/31/22 Isolated T140U 8,738’ 8,753’ 7,482’ 7,497’ 15’ 08/31/22 Isolated T140L 8,769’ 8,787’ 7,513’ 7,530’ 18’ 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 08/31/22 Isolated T146 9,021’ 9,035’ 7,762’ 7,775’ 14’ 04/06/22 Isolated T146 9,037’ 9,045’ 7,777’ 7,785’ 8’ 04/06/22 Isolated T146 9,042’ 9,055’ 7,782 7,795 13’ 09/11/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 08/25/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 08/08/17 Isolated T146 9,072’ 9,080’ 7,811 7,819 8’ 09/11/17 Isolated 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,221'9,061' (fish) Casing Collapse Structural Conductor Surface 4,790psi Intermediate Production 7,500psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker Swell Packer; N/A 1,298' MD/1,242' TVD; N/A 7,958'7,625'6,395' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 04CO 701C Same 7,950'4-1/2" ~2,128 psi 9,213' See Schematic Length February 18, 2025 N/A 9,213' Perforation Depth MD (ft): See Attached Schematic 6,890psi 120'120' 1,491' Size 120' 1,491' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,387' 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 C061505 (SHL) / ADL384372 (BHL) 217-063 50-133-20665-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s t N 666 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-064 By Gavin Gluyas at 8:08 am, Feb 10, 2025 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2025.02.07 20:20:05 -09'00' SFD 2/11/2025 Perforate BJM 2/13/25 10-404 *&: 2/18/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.18 09:06:11 -09'00' RBDMS JSB 021825 Well Prognosis Well Name: Kalotsa 4 API Number: 50-133-20665-00-00 Current Status: Producing Gas Well Permit to Drill Number: 217-063 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: 2754 psi @ 6258’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2128 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .70 psi/ft using 13.5 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(.70-0.1) = 2128 psi / .60 = 3530‘ TVD Top of Applicable Gas Pool: 1545’ MD/1425’ TVD (Beluga-Tyonek) Well Status: Online Gas producer – 1675 mscfd, 0 bwpd, 40 psi FTP Brief Well Summary Kalotsa 4 was drilled and completed in August 2017 targeting the deep Tyonek sands. Multiple Tyonek sands have been perforated over the years that have produced with very steep decline rates. The objective of this sundry is to add additional infill perforations to the Tyonek sands to increase the rate. Notes Regarding Wellbore Condition x Inclination o Max inclination = 55.1° at 2932’ MD o Max DLS: 7.02° @ 1719’ MD x Min ID o 3.833” (Drift ID of 4.5” tubing/liner) x Recent Tags o 9/20/23 Tag w/ 2.25 gauge ring at 7653' kb. Run CCL and Tandem gauges as per procedure. Pre-Sundry Steps: 1. RU slickline 2. PT lubricator to 250 psi low/ 2,500 psi high 3. D&T to TD w/ large OD drift to find updated tag and ensure wellbore is clean of any sand bridges. o Last SL tag was 7653’ KB in September 2023 but 25’ of cement was dump bailed on the plug. TOC ~7612’ 4. RDMO slickline Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate TY 3– TY 53 sands from bottom up with 2-7/8” 60 deg phased perf guns: Well Prognosis Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Btm MD Top TVD Btm TVD Footage TY_3 ±4,958' ±4,974' ±3,803' ±3,818' ±16' TY_3 ±4,988' ±4,994' ±3,831' ±3,836' ±6' TY_5 ±5,099' ±5,105' ±3,934' ±3,939' ±6' TY_5A ±5,138' ±5,152' ±3,971' ±3,984' ±14' TY_5B ±5,177' ±5,187' ±4,008' ±4,017' ±10' TY_6 ±5,285' ±5,291' ±4,111' ±4,116' ±6' TY_6 ±5,295' ±5,301' ±4,120' ±4,126' ±6' TY_7 ±5,382' ±5,388' ±4,204' ±4,210' ±6' TY_8 ±5,458' ±5,468' ±4,278' ±4,287' ±10' TY_8 ±5,472' ±5,486' ±4,291' ±4,305' ±14' TY_10 ±5,577' ±5,587' ±4,394' ±4,403' ±10' TY_12 ±5,920' ±5,926' ±4,728' ±4,733' ±6' TY_14 ±6,181' ±6,187' ±4,983' ±4,989' ±6' TY_16 ±6,350' ±6,368' ±5,148' ±5,166' ±18' TY_18 ±6,524' ±6,530' ±5,319' ±5,325' ±6' TY_37 ±6,764' ±6,770' ±5,554' ±5,560' ±6' TY_42 ±6,945' ±6,955' ±5,732' ±5,741' ±10' TY_53 ±7,485' ±7,505' ±6,258' ±6,277' ±20' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Updated by DMA 10-04-23 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 7,637’ / PBTVD = 6,406’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120' 7-5/8"Surf Csg 29.7 L-80 BTC 6.875”Surf 1,491’ 4-1/2"Prod Csg 12.6 L-80 DWC/C HT 3.958”Surf 9,213’ Capillary String 3/8”Ran 4/9/22 Surf 7,550’ JEWELRY DETAIL No.Depth ID OD Item 1 1,298’3.958”6.875”Baker Swell Packer 2 7,637’4.500”CIBP (8-31-2022) w/ 25’ cmt (TOC 7,612’ 9/28/23) 3 8,995’4.500”CIBP 4 9,054’4.500”CIBP w/ 5’ of cement 02/01/18 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2” 6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows Ratty TOC = ~840’ MD, with good TOC starting at ~1700’ PERFORATION DETAIL Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt SPF Date Status T6 5,222'5,249'4,050'4,076'27'6 9/29/23 Open T6 5,260'5,277'4,087'4,103'17'6 9/29/23 Open T7 5,355'5,363'4,178'4,186'8'6 9/29/23 Open T7 5,366'5,376'4,189'4,198'10'6 9/29/23 Open T7 5,407'5,417'4,228'4,238'10'6 9/29/23 Open T7 5,421'5,429'4,242'4,250'7'6 9/29/23 Open T8 5,443'5,447'4,263'4,267'4'6 9/29/23 Open T8 5,450'5,458'4,270'4,278'8'6 9/29/23 Open T9A 5,535'5,547'4,353'4,364'12'6 9/29/23 Open T10A 5,613'5,623'4,429'4,438'10'6 9/28/23 Open T10A 5,641'5,648'4,456'4,463'7'6 9/28/23 Open T10B 5,653'5,664'4,468'4,478'11'6 9/28/23 Open T11U 5,690’5,694’4,504’4,508’4'09/06/22 Open T11M 5,696’5,702’4,509’4,515’6'09/06/22 Open T11L 5,716’5,722’4,529’4,535’6'09/06/22 Open T11A 5,800’5,804’4,611’4,614’4'09/06/22 Open T12 5,888’5,905’4,696’4,713’17'09/06/22 Open T16A 6,332’6,350’5,131’5,148’18'09/01/22 Open T17U 6,387’6,407’5,185’5,204’20'09/01/22 Open T17L 6,414’6,434’5,211’5,231’20'09/01/22 Open T18U 6,509’6,520’5,304’5,315’11'08/31/22 Open T18M 6,537’6,547’5,332’5,341’10'08/31/22 Open T18L 6,550’6,560’5,344’5,354’10'08/31/22 Open T37U 6,799’6,823’5,589’5,612’24'08/31/22 Open T37L 6,816’6,828’5,605’5,617’12'08/31/22 Open PERFORATION DETAIL continued on following page T146 T140 - T142 4 TOF @ 9,061’ 01/31/18 Fish Description Lost in Hole 8890’ Slickline TS: ~25’ OAL, 3.5” OD: LIB 6/20/22 8920’ E-line TS: 32.5’ OAL, 3.60”OD: GR, JB, CCL, 1-7/16 RS, 1in FN 6/19/22 9061’ Weatherford WRP w/ catcher sub, wire and LIB 1/31/18 T115 T80 T65 3 T83 – T100 T69 T73 T118 T11 T12 T16 T17 T18 T37 2 T6-T8 T10 Updated by DMA 10-04-23 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PERFORATION DETAIL continued from previous page PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T65 7,687’ 7,707’ 6,455’ 6,475’ 20’ 6 08/31/22 Isolated T65L 7,707’ 7,734’ 6,475’ 6,501’ 27’ 08/31/22 Isolated T69 7,824’ 7,844’ 6,589’ 6,608’ 20’ 08/31/22 Isolated T73 7,918’ 7,927’ 6,680’ 6,689’ 9’ 08/31/22 Isolated T80 7,967’ 7,970’ 6,728’ 6,731’ 3’ 08/31/22 Isolated T80 7,984’ 7,995’ 6,745’ 6,755’ 11’ 6 08/31/22 Isolated T83 8,039’ 8,052’ 6,799’ 6,811’ 13’ 6 08/31/22 Isolated T87 8,152’ 8,162’ 6,909’ 6,919’ 10’ 08/31/22 Isolated T90U 8,187’ 8,198’ 6,943’ 6,954’ 11’ 6 08/31/22 Isolated T90M 8,235’ 8,241’ 6,990’ 6,996’ 6’ 6 08/31/22 Isolated T90L 8,266’ 8,281’ 7,020’ 7,035’ 15’ 6 08/31/22 Isolated T100 8,374’ 8,389’ 7,126’ 7,140’ 15’ 6 08/31/22 Isolated T115U 8,462’ 8,472’ 7,211’ 7,221’ 10’ 08/31/22 Isolated T115L 8,475’ 8,487’ 7,224’ 7,236’ 12’ 08/31/22 Isolated T115 8,489’ 8,504’ 7,238’ 7,252’ 15’ 6 08/31/22 Isolated T115 8,570’ 8,581’ 7,317’ 7,328’ 11’ 6 08/31/22 Isolated T115 8,583’ 8,596’ 7,330’ 7,343’ 13’ 6 08/31/22 Isolated T118 8,612’ 8,621’ 7,358’ 7,367’ 9’ 08/31/22 Isolated T140U 8,738’ 8,753’ 7,482’ 7,497’ 15’ 6 08/31/22 Isolated T140L 8,769’ 8,787’ 7,513’ 7,530’ 18’ 6 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 08/31/22 Isolated T146 9,021’ 9,035’ 7,762’ 7,775’ 14’ 6 04/06/22 Isolated T146 9,037’ 9,045’ 7,777’ 7,785’ 8’ 6 04/06/22 Isolated T146 9,042’ 9,055’ 7,782 7,795 13’ 6 09/11/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/25/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/08/17 Isolated T146 9,072’ 9,080’ 7,811 7,819 8’ 6 09/11/17 Isolated Updated by SRW 02-04-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 7,637’ / PBTVD = 6,406’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120' 7-5/8"Surf Csg 29.7 L-80 BTC 6.875”Surf 1,491’ 4-1/2"Prod Csg 12.6 L-80 DWC/C HT 3.958”Surf 9,213’ JEWELRY DETAIL No.Depth ID OD Item 1 1,298’3.958”6.875”Baker Swell Packer 2 7,637’4.500”CIBP (8-31-2022) w/ 25’ cmt (TOC 7,612’ 9/28/23) 3 8,995’4.500”CIBP 4 9,054’4.500”CIBP w/ 5’ of cement 02/01/18 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2” 6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows Ratty TOC = ~840’ MD, with good TOC starting at ~1700’ PERFORATION DETAIL Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt Date Status TY3 ±4,958'±4,974'±3,803'±3,818'±16'Proposed TBD TY3 ±4,988'±4,994'±3,831'±3,836'±6'Proposed TBD TY5 ±5,099'±5,105'±3,934'±3,939'±6'Proposed TBD TY5A ±5,138'±5,152'±3,971'±3,984'±14'Proposed TBD TY5B ±5,177'±5,187'±4,008'±4,017'±10'Proposed TBD T6 5,222'5,249'4,050'4,076'27'9/29/23 Open T6 5,260'5,277'4,087'4,103'17'9/29/23 Open TY6 ±5,285'±5,291'±4,111'±4,116'±6'Proposed TBD TY6 ±5,295'±5,301'±4,120'±4,126'±6'Proposed TBD T7 5,355'5,363'4,178'4,186'8'9/29/23 Open T7 5,366'5,376'4,189'4,198'10'9/29/23 Open TY7 ±5,382'±5,388'±4,204'±4,210'±6'Proposed TBD T7 5,407'5,417'4,228'4,238'10'9/29/23 Open T7 5,421'5,429'4,242'4,250'7'9/29/23 Open T8 5,443'5,447'4,263'4,267'4'9/29/23 Open T8 5,450'5,458'4,270'4,278'8'9/29/23 Open TY8 ±5,458'±5,468'±4,278'±4,287'±10'Proposed TBD TY8 ±5,472'±5,486'±4,291'±4,305'±14'Proposed TBD T9A 5,535'5,547'4,353'4,364'12'9/29/23 Open TY10 ±5,577'±5,587'±4,394'±4,403'±10'Proposed TBD T10A 5,613'5,623'4,429'4,438'10'9/28/23 Open T10A 5,641'5,648'4,456'4,463'7'9/28/23 Open T10B 5,653'5,664'4,468'4,478'11'9/28/23 Open T11U 5,690’5,694’4,504’4,508’4'09/06/22 Open T11M 5,696’5,702’4,509’4,515’6'09/06/22 Open T11L 5,716’5,722’4,529’4,535’6'09/06/22 Open T11A 5,800’5,804’4,611’4,614’4'09/06/22 Open T12 5,888’5,905’4,696’4,713’17'09/06/22 Open TY12 ±5,920'±5,926'±4,728'±4,733'±6'Proposed TBD TY14 ±6,181'±6,187'±4,983'±4,989'±6'Proposed TBD TY16 ±6,350'±6,368'±5,148'±5,166'±18'Proposed TBD T16A 6,332’6,350’5,131’5,148’18'09/01/22 Open T17U 6,387’6,407’5,185’5,204’20'09/01/22 Open T17L 6,414’6,434’5,211’5,231’20'09/01/22 Open T18U 6,509’6,520’5,304’5,315’11'08/31/22 Open TY18 ±6,524'±6,530'±5,319'±5,325'±6'Proposed TBD T18M 6,537’6,547’5,332’5,341’10'08/31/22 Open T18L 6,550’6,560’5,344’5,354’10'08/31/22 Open TY37 ±6,764'±6,770'±5,554'±5,560'±6'Proposed TBD T37U 6,799’6,823’5,589’5,612’24'08/31/22 Open T37L 6,816’6,828’5,605’5,617’12'08/31/22 Open TY42 ±6,945'±6,955'±5,732'±5,741'±10'Proposed TBD TY53 ±7,485'±7,505'±6,258'±6,277'±20'Proposed TBD PERFORATION DETAIL continued on following page T146 T140 - T142 4 TOF @ 9,061’ 01/31/18 Fish Description Lost in Hole 8890’ Slickline TS: ~25’ OAL, 3.5” OD: LIB 6/20/22 8920’ E-line TS: 32.5’ OAL, 3.60”OD: GR, JB, CCL, 1-7/16 RS, 1in FN 6/19/22 9061’ Weatherford WRP w/ catcher sub, wire and LIB 1/31/18 T115 T80 T65 3 T83 – T100 T69 T73 T118 T11 T12 T16 T17 T18 T37 2 T6-T8 T10 Updated by SRW 02-04-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PERFORATION DETAIL continued from previous page PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Date Status T65 7,687’ 7,707’ 6,455’ 6,475’ 20’ 08/31/22 Isolated T65L 7,707’ 7,734’ 6,475’ 6,501’ 27’ 08/31/22 Isolated T69 7,824’ 7,844’ 6,589’ 6,608’ 20’ 08/31/22 Isolated T73 7,918’ 7,927’ 6,680’ 6,689’ 9’ 08/31/22 Isolated T80 7,967’ 7,970’ 6,728’ 6,731’ 3’ 08/31/22 Isolated T80 7,984’ 7,995’ 6,745’ 6,755’ 11’ 08/31/22 Isolated T83 8,039’ 8,052’ 6,799’ 6,811’ 13’ 08/31/22 Isolated T87 8,152’ 8,162’ 6,909’ 6,919’ 10’ 08/31/22 Isolated T90U 8,187’ 8,198’ 6,943’ 6,954’ 11’ 08/31/22 Isolated T90M 8,235’ 8,241’ 6,990’ 6,996’ 6’ 08/31/22 Isolated T90L 8,266’ 8,281’ 7,020’ 7,035’ 15’ 08/31/22 Isolated T100 8,374’ 8,389’ 7,126’ 7,140’ 15’ 08/31/22 Isolated T115U 8,462’ 8,472’ 7,211’ 7,221’ 10’ 08/31/22 Isolated T115L 8,475’ 8,487’ 7,224’ 7,236’ 12’ 08/31/22 Isolated T115 8,489’ 8,504’ 7,238’ 7,252’ 15’ 08/31/22 Isolated T115 8,570’ 8,581’ 7,317’ 7,328’ 11’ 08/31/22 Isolated T115 8,583’ 8,596’ 7,330’ 7,343’ 13’ 08/31/22 Isolated T118 8,612’ 8,621’ 7,358’ 7,367’ 9’ 08/31/22 Isolated T140U 8,738’ 8,753’ 7,482’ 7,497’ 15’ 08/31/22 Isolated T140L 8,769’ 8,787’ 7,513’ 7,530’ 18’ 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 08/31/22 Isolated T146 9,021’ 9,035’ 7,762’ 7,775’ 14’ 04/06/22 Isolated T146 9,037’ 9,045’ 7,777’ 7,785’ 8’ 04/06/22 Isolated T146 9,042’ 9,055’ 7,782 7,795 13’ 09/11/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 08/25/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 08/08/17 Isolated T146 9,072’ 9,080’ 7,811 7,819 8’ 09/11/17 Isolated STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240112 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL Please include current contact information if different from above. T38273 T38275 T38277 T38278 T38279 T38280 T38280 T38281 T38282 T38283 T38284 T38285 T38286 T38287 T38287 T38288 T38288 T38289 T38289 T38289 T38290 T38290 1/18/2024 KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 11:52:00 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,221 feet See schematic feet true vertical 7,958 feet 9,061(fish)feet Effective Depth measured 7,625 feet 1,298 feet true vertical 6,395 feet 1,242 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A 1,298 MD Packers and SSSV (type, measured and true vertical depth)Baker Swell Pkr 1,242 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 323-523 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 238 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 81 Size 120' 0 795930 0 400 264 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-063 50-133-20665-00-00 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: C061505 (SHL) / ADL384372 (BHL) Ninilchik / Beluga-Tyonek Gas Pool NINU Kalotsa 4 Plugs Junk measured Length Production Liner 9,213' Casing Structural 7,950'9,213' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,491' 7,500psi 6,890psi 8,430psi 1,491' 1,387' Burst Collapse 4,790psi p k ft t Fra O s O 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 8:36 am, Oct 11, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.10.10 15:41:04 - 08'00' Noel Nocas (4361) Rig Start Date End Date E-Line 9/28/23 9/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 4 50-133-20665-00-00 217-063 09/28/2023 - Thursday PJSM, PTW, Mobe to location, R/U E-line, P/U lubricator & Tool string w/50' of 3" dump bailer fill with 8 gal cmt. P/T lubricator 2500psi good. RIH t/ tag CIBP, set @7637', P/U dump cmt bailer, POOH, t/surface, MT bailer. Re-load bailer with 8 gal CMT, RIH dump cmt above est top of cmt ~7625', POOH MT bailer. M/U 2 7/8" gun #1 loaded w/11' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass up f/5700' to 5400', send to Geo for correlation, good, pull into depth, 5640.5 ccl depth, 12.5' to top shot, perf 5653-5664' No initial change in pressure, 44 psi 5 min 44 psi 10 min 44 psi 15 min 44 psi OOH bull plug dry, all shots fired. M/U 2 7/8" gun #2 loaded w/7' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, send to Geo for correlation, good, pull into depth, 5631.5 ccl depth, 9.5' to top shot, perf 5641-5648' No initial change in pressure, 44 psi 5 min 44 psi 10 min 44 psi 15 min 44 psi OOH bull plug dry, all shots fired. M/U 2 7/8" gun #3 loaded w/10' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, send to Geo for correlation, good, pull into depth, 5598.5 ccl depth, 14.5' to top shot, perf 5613-5623' No initial change in pressure, 44 psi 5 min 44 psi 10 min 44 psi 15 min 44 psi OOH bull plug splash of water, all shots fired. M/U 2 7/8" gun #4 loaded w/10' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, send to Geo for correlation, good, pull into depth, 5598.5 ccl depth, 14.5' to top shot, perf 5535-5547' No initial change in pressure, 44 psi 5 min 44 psi 10 min 44 psi 15 min 44 psi OOH bull plug damp, all shots fired. Secure well, SDFN Rig Start Date End Date E-Line 9/28/23 9/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 4 50-133-20665-00-00 217-063 PJSM, PTW, warm Eq. & fuel, rehead rope socket. M/U 2 3/4" gun #5 & 6, 6 SPF, 60 deg phasing, RIH & pull correlation pass, send to Geo for correlation, good, pull gun 5 w/8' of shots into position, 5433' ccl depth, 17' to top shot, perf T-8 5450-5458' No initial change in pressure, 39 psi 5 min 40 psi 10 min 40 psi 15 min 40 psi initial flow rate ~425, flow rate after shooting ~455MCFD. Pull gun 6 w/4' of shots into position, 5431.5' ccl depth, 11' to top shot, perf T-8 5443-5447' No initial change in pressure, 40 psi 5 min 40 psi 10 min 40 psi 15 min 40 psi POOH all shots fired, both bull plugs wet, flow rate ~510MCFD. M/U 2 7/8" gun #7 loaded w/8' of shots 6 SPF, 60 deg phasing, RIH & pulled correlation pass for rest of gun runs send to Geo for correlation, good for running rest of guns. pull into depth, 5404 ccl depth, 17' to top shot, perf T-7 5421-5429' no initial change in pressure, 40 psi 5 min 42 psi 10 min 42 psi 15 min 42 psi POOH all shots fired, bull plug wet, flow rate ~800MCFD. M/U 2 7/8" gun #8 loaded w/10' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, good, pull into depth, 5392.5' ccl depth, 14.5' to top shot, perf T-7 5407-5417' no initial change in pressure, 43 psi 09/29/2023 - Friday Rig Start Date End Date E-Line 9/28/23 9/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 4 50-133-20665-00-00 217-063 5 min 45 psi 10 min 45 psi 15 min 47 psi POOH all shots fired, bull plug wet, flow rate ~1045MCFD. M/U 2 7/8" gun #9 loaded w/10' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, good, pull into depth, 5351.5' ccl depth, 14.5' to top shot, perf T-7 5366-5376' no initial change in pressure, 47 psi 5 min 47 psi 10 min 48 psi 15 min 48 psi POOH all shots fired, bull plug wet, flow rate ~1075MCFD. M/U 2 7/8" gun #10 loaded w/8' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, good, pull into depth, 5338' ccl depth, 17' to top shot, perf T-7 5355-5363' no initial change in pressure, 47 psi 5 min 47 psi 10 min 47 psi 15 min 48 psi POOH all shots fired, bull plug wet. flow rate ~1110MCFD. Discuss options of flowing or moving forward, decision made to finish perforations. M/U 2 7/8" gun #11 loaded w/17' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, good, pull into depth, 5248.5' ccl depth, 11.5 to top shot, perf T-6 5260-5277' initial PSI 48 50 after shot 5 min 61 10 min 62 15 min 65 OH all shots fired, wet gun, flow rate 2220MCFD. M/U 2 3/4" gun #11 loaded w/27' of shots 6 SPF, 60 deg phasing, RIH & pull correlation pass, good, pull into depth, 5211.5' ccl depth, 11.5 to top shot, perf T-6 5222-5249' initial PSI 65 78 after shot 5 min 184 10 min 181 15 min 187 OOH all shots fired, wet gun, flow rate 6910MCFD @ 192psi, Production pinched flow back to 2815MCFD 570psi Secure well SDFN Updated by DMA 10-04-23 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 7,637 / PBTVD = 6,406 TD = 9,221 / TVD = 7,958 RKB to GL = 18 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 X-56 Weld 15.01Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875Surf 1,491 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958Surf 9,213 Capillary String 3/8Ran 4/9/22 Surf 7,550 JEWELRY DETAIL No. Depth ID OD Item 1 1,298 3.958 6.875Baker Swell Packer 2 7,637 4.500 CIBP (8-31-2022) w/ 12 cmt (TOC 7,625 9/28/23) 3 8,995 4.500CIBP 4 9,054 4.500 CIBP w/ 5 of cement 02/01/18 1 16 7-5/8 6-3/4 Hole 4-1/2 RA @ 5,490 RA @ 6,490 RA @ 7,500 RA @ 8,496 OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8 hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2 6-3/4 hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows Ratty TOC = ~840 MD, with good TOC starting at ~1700 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T6 5,222' 5,249' 4,050' 4,076' 27' 6 9/29/23 Open T6 5,260' 5,277' 4,087' 4,103' 17' 6 9/29/23 Open T7 5,355' 5,363' 4,178' 4,186' 8' 6 9/29/23 Open T7 5,366' 5,376' 4,189' 4,198' 10' 6 9/29/23 Open T7 5,407' 5,417' 4,228' 4,238' 10' 6 9/29/23 Open T7 5,421' 5,429' 4,242' 4,250' 7' 6 9/29/23 Open T8 5,443' 5,447' 4,263' 4,267' 4' 6 9/29/23 Open T8 5,450' 5,458' 4,270' 4,278' 8' 6 9/29/23 Open T9A 5,535' 5,547' 4,353' 4,364' 12' 6 9/29/23 Open T10A 5,613' 5,623' 4,429' 4,438' 10' 6 9/28/23 Open T10A 5,641' 5,648' 4,456' 4,463' 7' 6 9/28/23 Open T10B 5,653' 5,664' 4,468' 4,478' 11' 6 9/28/23 Open T11U 5,690 5,694 4,504 4,5084' 09/06/22 Open T11M 5,696 5,702 4,509 4,5156' 09/06/22 Open T11L 5,716 5,722 4,529 4,5356' 09/06/22 Open T11A 5,800 5,804 4,611 4,6144' 09/06/22 Open T12 5,888 5,905 4,696 4,71317' 09/06/22 Open T16A 6,332 6,350 5,131 5,14818' 09/01/22 Open T17U 6,387 6,407 5,185 5,20420' 09/01/22 Open T17L 6,414 6,434 5,211 5,23120' 09/01/22 Open T18U 6,509 6,520 5,304 5,31511' 08/31/22 Open T18M 6,537 6,547 5,332 5,34110' 08/31/22 Open T18L 6,550 6,560 5,344 5,35410' 08/31/22 Open T37U 6,799 6,823 5,589 5,61224' 08/31/22 Open T37L 6,816 6,828 5,605 5,61712' 08/31/22 Open PERFORATION DETAIL continued on following page T146 T140 - T142 4 TOF @ 9,061 01/31/18 Fish Description Lost in Hole 8890 Slickline TS: ~25 OAL, 3.5 OD: LIB 6/20/22 8920 E-line TS: 32.5 OAL, 3.60OD: GR, JB, CCL, 1-7/16 RS, 1in FN 6/19/22 9061 Weatherford WRP w/ catcher sub, wire and LIB 1/31/18 T115 T80 T65 3 T83 T100 T69 T73 T118 T11 T12 T16 T17 T18 T37 2 T6-T8 T10 Updated by DMA 10-04-23 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PERFORATION DETAIL continued from previous page PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T65 7,687 7,707 6,455 6,475 20 6 08/31/22 Isolated T65L 7,707 7,734 6,475 6,501 27 08/31/22 Isolated T69 7,824 7,844 6,589 6,608 20 08/31/22 Isolated T73 7,918 7,927 6,680 6,689 9 08/31/22 Isolated T80 7,967 7,970 6,728 6,731 3 08/31/22 Isolated T80 7,984 7,995 6,745 6,755 11 6 08/31/22 Isolated T83 8,039 8,052 6,799 6,811 13 6 08/31/22 Isolated T87 8,152 8,162 6,909 6,919 10 08/31/22 Isolated T90U 8,187 8,198 6,943 6,954 11 6 08/31/22 Isolated T90M 8,235 8,241 6,990 6,996 6 6 08/31/22 Isolated T90L 8,266 8,281 7,020 7,035 15 6 08/31/22 Isolated T100 8,374 8,389 7,126 7,140 15 6 08/31/22 Isolated T115U 8,462 8,472 7,211 7,221 10 08/31/22 Isolated T115L 8,475 8,487 7,224 7,236 12 08/31/22 Isolated T115 8,489 8,504 7,238 7,252 15 6 08/31/22 Isolated T115 8,570 8,581 7,317 7,328 11 6 08/31/22 Isolated T115 8,583 8,596 7,330 7,343 13 6 08/31/22 Isolated T118 8,612 8,621 7,358 7,367 9 08/31/22 Isolated T140U 8,738 8,753 7,482 7,497 15 6 08/31/22 Isolated T140L 8,769 8,787 7,513 7,530 18 6 08/31/22 Isolated T142 8,843 8,862 7,585 7,604 19 6 08/31/22 Isolated T142 8,843 8,862 7,585 7,604 19 6 08/31/22 Isolated T146 9,021 9,035 7,762 7,775 14 6 04/06/22 Isolated T146 9,037 9,045 7,777 7,785 8 6 04/06/22 Isolated T146 9,042 9,055 7,782 7,795 13 6 09/11/17 Isolated T146 9,056 9,076 7,795 7,815 20 6 08/25/17 Isolated T146 9,056 9,076 7,795 7,815 20 6 08/08/17 Isolated T146 9,072 9,080 7,811 7,819 8 6 09/11/17 Isolated 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,221'9,061' (fish) Casing Collapse Structural Conductor 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 C061505 (SHL) / ADL384372 (BHL) 217-063 50-133-20665-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 1,387' Size 120' 1,491' MD See Attached Schematic 6,890psi 120'120' 1,491' September 29, 2023 N/A 9,213' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 NINU Kalotsa 4CO 701C Same 7,950'4-1/2" ~1,910 psi 9,213' 9,054' Length Baker Swell Packer; N/A 1,298' MD/1,242' TVD; N/A 7,958'9,049'7,789' Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s t _ N 666 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 2:29 pm, Sep 15, 2023 323-523 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.09.15 13:37:25 - 08'00' Noel Nocas (4361) Dump bail 25' of cement on top of CIBP at 7637' md before adding perfs. MDG 9/18/2023 10-404 DSR-9/15/23BJM 9/22/23*&:JLC 9/25/2023 09/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.09.25 09:24:44 -08'00' RBDMS JSB 092623 Well Prognosis Well Name: Kalotsa-04 API Number: 50-133-20665-00-00 Current Status: Producing Gas Well Permit to Drill Number: 217-063 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: ~2471 psi @ 5617’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~1910 psi (Max expected BHP - gas to surface) Well Status: Online producer making 230 mcfd @ 41 psi, no water to surface (below unload rate) Brief Well Summary Kalotsa 4 is a Tyonek sand producer that fell below the unload rate in May of 2022 and has continued to decline. The objective of the sundry is to increase productivity by adding uphole Tyonek sands. Notes Regarding Wellbore Condition: - 4-1/2” monobore drilled in 2017 - Existing open perfs: 5690’ – 6828’ MD (Gross) - TOC @ 1700’ 8/31/22 CIBP set at 7637’ 9/06/22 T11-T12 perfs added (5690-5905’ gross interval) Procedure 1. RU E-line, PT lubricator to 2500 psi 2. Perforate the below sands from the bottom up while flowing: Zone Top MD Bottom MD Top TVD Bottom TVD TOTAL [FT] T10B 5653 5664 4468 4475 11 T10B 5641 5648 4457 4462 7 T10A 5613 5623 4429 4439 10 T10 5578 5585 4394 4401 7 T9A 5535 5547 4353 4364 12 T8 5470 5484 4289 4303 14 T8 5450 5458 4270 4277 8 T8 5443 5447 4263 4267 4 T7 5421 5429 4242 4249 8 T7 5407 5417 4228 4238 10 T7 5366 5376 4189 4198 10 T7 5355 5363 4178 4185 8 T6 5260 5277 4086 4103 17 T6 5222 5249 4051 4076 27 T5 5098 5106 3933 3940 8 T3 4959 4967 3804 3811 8 Dump bail 25' of cement on top of CIBP at 7637' MD before perforating. -bjm Well Prognosis a) If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic Updated by JLL 09/22/22 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 7,637’ / PBTVD = 6,406’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875” Surf 1,491’ 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958” Surf 9,213’ Capillary String 3/8” Ran 4/9/22 Surf 7,550’ JEWELRY DETAIL No. Depth ID OD Item 1 1,298’ 3.958” 6.875” Baker Swell Packer 2 7,637’ 4.500” CIBP (8-31-2022) 3 8,995’ 4.500” CIBP 4 9,054’ 4.500” CIBP w/ 5’ of cement 02/01/18 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2” 6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows Ratty TOC = ~840’ MD, with good TOC starting at ~1700’ PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T11U 5,690’ 5,694’ 4,504’ 4,508’ 4 09/06/22 Open T11M 5,696’ 5,702’ 4,509’ 4,515’ 6 09/06/22 Open T11L 5,716’ 5,722’ 4,529’ 4,535’ 6 09/06/22 Open T11A 5,800’ 5,804’ 4,611’ 4,614’ 4 09/06/22 Open T12 5,888’ 5,905’ 4,696’ 4,713’ 17 09/06/22 Open T16A 6,332’ 6,350’ 5,131’ 5,148’ 18 09/01/22 Open T17U 6,387’ 6,407’ 5,185’ 5,204’ 20 09/01/22 Open T17L 6,414’ 6,434’ 5,211’ 5,231’ 20 09/01/22 Open T18U 6,509’ 6,520’ 5,304’ 5,315’ 11 08/31/22 Open T18M 6,537’ 6,547’ 5,332’ 5,341’ 10 08/31/22 Open T18L 6,550’ 6,560’ 5,344’ 5,354’ 10 08/31/22 Open T37U 6,799’ 6,823’ 5,589’ 5,612’ 24 08/31/22 Open T37L 6,816’ 6,828’ 5,605’ 5,617’ 12 08/31/22 Open T65 7,687’ 7,707’ 6,455’ 6,475’ 20’ 6 08/31/22 Isolated T65L 7,707’ 7,734’ 6,475’ 6,501’ 27’ 08/31/22 Isolated T69 7,824’ 7,844’ 6,589’ 6,608’ 20’ 08/31/22 Isolated T73 7,918’ 7,927’ 6,680’ 6,689’ 9’ 08/31/22 Isolated T80 7,967’ 7,970’ 6,728’ 6,731’ 3’ 08/31/22 Isolated T80 7,984’ 7,995’ 6,745’ 6,755’ 11’ 6 08/31/22 Isolated T83 8,039’ 8,052’ 6,799’ 6,811’ 13’ 6 08/31/22 Isolated T87 8,152’ 8,162’ 6,909’ 6,919’ 10’ 08/31/22 Isolated T90U 8,187’ 8,198’ 6,943’ 6,954’ 11’ 6 08/31/22 Isolated T90M 8,235’ 8,241’ 6,990’ 6,996’ 6’ 6 08/31/22 Isolated T90L 8,266’ 8,281’ 7,020’ 7,035’ 15’ 6 08/31/22 Isolated T100 8,374’ 8,389’ 7,126’ 7,140’ 15’ 6 08/31/22 Isolated T115U 8,462’ 8,472’ 7,211’ 7,221’ 10’ 08/31/22 Isolated T115L 8,475’ 8,487’ 7,224’ 7,236’ 12’ 08/31/22 Isolated T115 8,489’ 8,504’ 7,238’ 7,252’ 15’ 6 08/31/22 Isolated T115 8,570’ 8,581’ 7,317’ 7,328’ 11’ 6 08/31/22 Isolated T115 8,583’ 8,596’ 7,330’ 7,343’ 13’ 6 08/31/22 Isolated T118 8,612’ 8,621’ 7,358’ 7,367’ 9’ 08/31/22 Isolated T140U 8,738’ 8,753’ 7,482’ 7,497’ 15’ 6 08/31/22 Isolated T140L 8,769’ 8,787’ 7,513’ 7,530’ 18’ 6 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 08/31/22 Isolated T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 08/31/22 Isolated T146 9,021’ 9,035’ 7,762’ 7,775’ 14’ 6 04/06/22 Isolated T146 9,037’ 9,045’ 7,777’ 7,785’ 8’ 6 04/06/22 Isolated T146 9,042’ 9,055’ 7,782 7,795 13’ 6 09/11/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/25/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/08/17 Isolated T146 9,072’ 9,080’ 7,811 7,819 8’ 6 09/11/17 Isolated T146 T140 - T142 4 TOF @ 9,061’ 01/31/18 Fish Description Lost in Hole 8890’ Slickline TS: ~25’ OAL, 3.5” OD: LIB 6/20/22 8920’ E-line TS: 32.5’ OAL, 3.60”OD: GR, JB, CCL, 1-7/16 RS, 1in FN 6/19/22 9061’ Weatherford WRP w/ catcher sub, wire and LIB 1/31/18 T115 T80 T65 3 T83 –T100 T69 T73 T118 T11 T12 T16 T17 T18 T37 2 Updated by DMA 09-15-23 PROPOSED Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 7,637’ / PBTVD = 6,406’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120' 7-5/8"Surf Csg 29.7 L-80 BTC 6.875”Surf 1,491’ 4-1/2"Prod Csg 12.6 L-80 DWC/C HT 3.958”Surf 9,213’ Capillary String 3/8”Ran 4/9/22 Surf 7,550’ JEWELRY DETAIL No.Depth ID OD Item 1 1,298’3.958”6.875”Baker Swell Packer 2 7,637’4.500”CIBP (8-31-2022) 3 8,995’4.500”CIBP 4 9,054’4.500”CIBP w/ 5’ of cement 02/01/18 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2” 6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows Ratty TOC = ~840’ MD, with good TOC starting at ~1700’ PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt SPF Date Status T3- T10B ±4,959’±5,664’±3,804’±4,475’4 Proposed TBD T11U 5,690’5,694’4,504’4,508’4 09/06/22 Open T11M 5,696’5,702’4,509’4,515’6 09/06/22 Open T11L 5,716’5,722’4,529’4,535’6 09/06/22 Open T11A 5,800’5,804’4,611’4,614’4 09/06/22 Open T12 5,888’5,905’4,696’4,713’17 09/06/22 Open T16A 6,332’6,350’5,131’5,148’18 09/01/22 Open T17U 6,387’6,407’5,185’5,204’20 09/01/22 Open T17L 6,414’6,434’5,211’5,231’20 09/01/22 Open T18U 6,509’6,520’5,304’5,315’11 08/31/22 Open T18M 6,537’6,547’5,332’5,341’10 08/31/22 Open T18L 6,550’6,560’5,344’5,354’10 08/31/22 Open T37U 6,799’6,823’5,589’5,612’24 08/31/22 Open T37L 6,816’6,828’5,605’5,617’12 08/31/22 Open T65 7,687’7,707’6,455’6,475’20’6 08/31/22 Isolated T65L 7,707’7,734’6,475’6,501’27’08/31/22 Isolated T69 7,824’7,844’6,589’6,608’20’08/31/22 Isolated T73 7,918’7,927’6,680’6,689’9’08/31/22 Isolated T80 7,967’7,970’6,728’6,731’3’08/31/22 Isolated T80 7,984’7,995’6,745’6,755’11’6 08/31/22 Isolated T83 8,039’8,052’6,799’6,811’13’6 08/31/22 Isolated T87 8,152’8,162’6,909’6,919’10’08/31/22 Isolated T90U 8,187’8,198’6,943’6,954’11’6 08/31/22 Isolated T90M 8,235’8,241’6,990’6,996’6’6 08/31/22 Isolated T90L 8,266’8,281’7,020’7,035’15’6 08/31/22 Isolated T100 8,374’8,389’7,126’7,140’15’6 08/31/22 Isolated T115U 8,462’8,472’7,211’7,221’10’08/31/22 Isolated T115L 8,475’8,487’7,224’7,236’12’08/31/22 Isolated T115 8,489’8,504’7,238’7,252’15’6 08/31/22 Isolated T115 8,570’8,581’7,317’7,328’11’6 08/31/22 Isolated T115 8,583’8,596’7,330’7,343’13’6 08/31/22 Isolated T118 8,612’8,621’7,358’7,367’9’08/31/22 Isolated T140U 8,738’8,753’7,482’7,497’15’6 08/31/22 Isolated T140L 8,769’8,787’7,513’7,530’18’6 08/31/22 Isolated T142 8,843’8,862’7,585’7,604’19’6 08/31/22 Isolated T142 8,843’8,862’7,585’7,604’19’6 08/31/22 Isolated T146 9,021’9,035’7,762’7,775’14’6 04/06/22 Isolated T146 9,037’9,045’7,777’7,785’8’6 04/06/22 Isolated T146 9,042’9,055’7,782 7,795 13’6 09/11/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/25/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/08/17 Isolated T146 9,072’9,080’7,811 7,819 8’6 09/11/17 Isolated T146 T140 - T142 4 TOF @ 9,061’ 01/31/18 Fish Description Lost in Hole 8890’ Slickline TS: ~25’ OAL, 3.5” OD: LIB 6/20/22 8920’ E-line TS: 32.5’ OAL, 3.60”OD: GR, JB, CCL, 1-7/16 RS, 1in FN 6/19/22 9061’ Weatherford WRP w/ catcher sub, wire and LIB 1/31/18 T115 T80 T65 3 T83 – T100 T69 T73 T118 T11 T12 T16 T17 T18 T37 2 Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221215 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14A 50133205390100 213196 9/22/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 10/24/2022 YELLOW JACKET PERF-GPT CLU 05RD 50133204740100 215160 7/15/2022 YELLOW JACKET PLUG-PERF CLU 10 50133205530000 205106 7/16/2022 YELLOW JACKET PERF KALOTSA 4 50133206650000 217063 8/24/2022 YELLOW JACKET PERF MPU K-09 50029232470000 205014 12/11/2022 READ CaliperSurvey Please include current contact information if different from above. T37376 T37377 T37378 T37379 T37380 T37381 By Meredith Guhl at 10:10 am, Dec 16, 2022 KALOTSA 4 50133206650000 217063 8/24/2022 YELLOW JACKET PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.16 10:11:16 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221123 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PAXTON 6 50133207070000 222054 8/1/2022 Yellowjacket PERF BCU-7A 50133202840100 214060 8/2/2022 Yellowjacket GPT-PERF KBU 43-07Y 50133206250000 214019 8/3/2022 Yellowjacket PERF KBU 22-06Y 50133206500000 215044 8/4/2022 Yellowjacket GPT-PERF SRU 32A-33 50133101640100 191014 8/21/2022 Yellowjacket GPT-PERF HVB 16A 50231200400100 222070 8/23/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/26/2022 Yellowjacket PERF HVB-16A 50231200400100 222070 8/27/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/29/2022 Yellowjacket PERF KALOTSA 4 50133206650000 217063 9/1/2022 Yellowjacket GPT-PERF KALOTSA 4 50133206650000 217063 9/6/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. By Meredith Guhl at 9:26 am, Nov 29, 2022 T37305 T37306 T37306 T37307 T37307 T37308 T37309 T37310 T37311 T37311 T37312 KALOTSA 4 50133206650000 217063 9/1/2022 Yellowjacket GPT-PERF KALOTSA 4 50133206650000 217063 9/6/2022 Yellowjacket PERF-GPT Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 09:43:24 -09'00' By Samantha Carlisle at 8:18 am, Sep 23, 2022 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220902 Well API #PTD #Log Date Log Company Log Type Notes AOGCC Eset # END 3-11 50029218480000 188087 8/1/2022 Halliburton CALIPER + Report KALOTSA 4 50133206650000 217063 7/18/2022 Halliburton PPROF + Processing KBU 22-06Y 50133206500000 215044 7/14/2022 Halliburton PPROF + Processing KTU 24-06H 50133204900000 199073 7/21/2022 Halliburton PPROF + Processing KU 24-05B 50133206830000 219072 7/20/2022 Halliburton PPROF + Processing MPU C-24A 50029230200100 209134 7/28/2022 Halliburton COIL FLAG MPU I-17 50029232120000 204098 7/19/2022 Halliburton FREEPOINT NS-10 50029229850000 200182 7/23/2022 Halliburton CALIPER + Report NS-32 50029231790000 203158 7/24/2022 Halliburton CALIPER + Report PBU 18-02C 50029207620300 213009 7/14/2022 Halliburton CAST/CBL PBU C-10B 50029203710200 211092 7/15/2022 Halliburton PPROF + Processing PBU L5-03 50029236230000 219033 7/25/2022 Halliburton PPROF + Processing Please include current contact information if different from above. T36973 T36974 T36975 T36976 T36977 T36978 T36979 T36980 T36981 T36982 T36983 T36984 KALOTSA 4 50133206650000 217063 7/18/2022 Halliburton PPROF + Processing Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.07 11:00:16 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Jacob Flora Cc:Roby, David S (OGC); Davies, Stephen F (OGC); Ryan Thompson; Matthew Petrowsky; Christopher Stone Subject:RE: Kalotsa 4 AOGCC 10-403 321-466 PTD 217-063 Approved 09-21-21 (Request to add perf zones) Date:Monday, August 29, 2022 12:01:00 PM Hilcorp has approval to add the additional perfs listed below in red, between 6509’ and 6828’ MD. The 10-404 for this sundry should be submitted after these additional perf intervals are added. Additional perf intervals beyond those listed in this email may be applied for with an additional sundry application. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Monday, August 29, 2022 11:37 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Matthew Petrowsky <mpetrowsky@hilcorp.com>; Christopher Stone <Christopher.Stone@hilcorp.com> Subject: Kalotsa 4 AOGCC 10-403 321-466 PTD 217-063 Approved 09-21-21 (Request to add perf zones) Hello Bryan, We would like to add a few more sand intervals within the already approved gross interval. The below sands in black are already approved, we request to add the sands in red (T18-37). Please let us know if you need anything further in your review, Thanks, Jake Requesting to add (in red): Kalotsa 4 Perforation Table – 08.29.22 Sand Perforation Top Perforation Bottom Perforation Top Perforation Bottom Total Footage (MD)(MD)(TVD)(TVD)(MD) T-11u ±5,690’±5,694’±4,504’±4,507’4’ T-11m ±5,696’±5,702’±4,509’±4,515’6’ T-11L ±5,716’±5,722’±4,529’±4,534’6’ T-11A ±5,800’±5,804’±4,611’±4,614’4’ T-12 ±5,888’±5,905’±4,696’±4,713’17’ T-16A ±6,332’±6,350’±5,131’±5,148’18’ T-17u ±6,387’±6,407’±5,181’±5,205’20’ T-17L ±6,414’±6,434’±5,211’±5,231’20‘ T-18u ±6,509’±6,520’±5,305’±5,315’11‘ T-18m ±6,537’±6,547’±5,332’±5,341’10‘ T-18L ±6,550’±6,560’±5,344’±5,354’10‘ T-37u ±6,791’±6,815’±5,581’±5,604’24’ T-37L ±6,816’±6,828’±5,605’±5,617’12’ Approved per 8/4 email Approved per Sundry 321-466: 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 ifyou have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediatelynotify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and anyattachments 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 considersappropriate. 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 ifyou have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediatelynotify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Jacob Flora Cc:Roby, David S (OGC); Davies, Stephen F (OGC) Subject:RE: Kalotsa 4 AOGCC 10-403 321-466 PTD 217-063 Approved 09-21-21 (Request to add perf zones) Date:Thursday, August 4, 2022 10:33:00 AM Jake, Hilcorp has approval to proceed with the additional perf intervals listed below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Wednesday, August 3, 2022 3:27 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Kalotsa 4 AOGCC 10-403 321-466 PTD 217-063 Approved 09-21-21 (Request to add perf zones) Hi Bryan, Per sundry 321-466 we added multiple perforations from the T-83 to T-146 sands which were within the previously perforated layers. The cap string was re-run and the well still struggled to unload and stabilize. Hilcorp requests to add the below sands to the existing open sundry to see if they will kick the well off above unloading rate. To note these sands are within but not specified in the open sundry. I’ve attached a current WBD for review. Please let me know if you need more information in your review. Thanks for your time, Jake Requested sands to add: Already approved per 321-466: 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 anyattachments 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 considersappropriate. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/10/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KALOTSA 4 (PTD 217-063) GPT/PLUG/PERF 4/06/2022 Please include current contact information if different from above. 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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: _Patch / N2 / 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? 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): 9,221'9,061' (fish) Casing Collapse Structural Conductor 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: September 25, 2021 N/A 9,213' Perforation Depth MD (ft): See Attached Schematic 9,213' 7,950'4-1/2" 16" 7-5/8" 120' 1,491'6,890psi 120' 1,387' 120' 1,491' N/A TVD Burst N/A 8,430psi MDLength Size 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 (BHL) 217-063 50-133-20665-00-00 Kalotsa 4 Ninilchik Field - Beluga/Tyonek Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic ryan.rupert @hilcorp.com 7,958'9,049'7,789'~2,677 psi 9,054' Baker Swell Packer; N/A 1,298' MD/1,242' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 3:25 pm, Sep 10, 2021 321-466 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.10 14:47:54 -08'00' Taylor Wellman (2143) DSR-9/13/21SFD 9/10/2021 Adjust the 4-1/2" x OH cement top on the wellbore diagram according to the CBL log, which indicates TOC is ~1700' md. The 10-404 should reflect the updated TOC. BJM 9/20/21 10-404 dts 9/21/2021 JLC 9/21/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.21 14:36:14 -08'00' RBDMS HEW 9/22/2021 Well: Kalotsa-04 Date: 9/10/2021 Well Name:Kalotsa-04 API Number:50-133-20665-00-00 Current Status:Producing Gas Well Permit to Drill Number:217-063 Regulatory Contact:Donna Ambruz (907) 777-8305 (O) First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (M) Second Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Maximum Expected BHP:~ 3438 psi @ 7604’ TVD Based on T-142 pressure from Kal-03’s RFT in 2017 Max. Potential Surface Pressure:~ 2677 psi Using Max BHP minus 0.1 psi/ft. gas gradient to surface Brief Well Summary Kalotsa-04 was a steady gas producer at >1.5MMCFD for the past year. The well has been making 15-25bwpd. It had been requiring multiple soap sticks each day and was falling off to <500mcf multiple times recently. A cap string was run 8/27/21, but didn’t make a substantial improvement in performance. More perfs are proposed to get the well above its unloading rate. Given the water production, re-installing the cap string maybe necessary, and is included in this sundry. The purpose of this work/sundry is to add perfs to increase production from Kalotsa-04. Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Max inclination = 55deg at 1748’ MD x Drifts o 8/26/21: SL RIH with a 3.72” blind box and tagged PBTD at 9056’ SLMD o 1/13/20: EL made it to 7707’ MD with a 20’ x 2-7/8” perf gun and logging sub while SI o 6/21/19: EL made it to 7995’ MD with a 15’ x 2-7/8” perf gun and logging sub while flowing Nitrogen Risk x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority o add perfs to increase production from Kalotsa-04. Well: Kalotsa-04 Date: 9/10/2021 Cap String Procedure 1. RU Cap String Truck. 2. Pull 3/8” capillary line from 7400’ MD 3. RD Cap String Truck, and turn well over to production. E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3,500 psi High 3. Rig up perf gun (Likely 2-7/8” – 3-3/8” 4-6 spf) 4. RIH, determine FL and obtain a corrected tag of PBTD. 5. Perforate the sands listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) T-11 ±5,687'±5,704'±4,500'±4,517'18' T-12 ±5,885'±5,898'±4,693'±4,706'13' T-16A ±6,343'±6,365'±5,142'±5,163'22' T-17 ±6,382'±6,441'±5,180'±5,237'59' T-18 ±6,503'±6,522'±5,298'±5,316'19' T-37 ±6,792'±6,827'±5,581'±5,616'36' T-53 ±7,488'±7,500'±6,261'±6,273'12' T-69 ±7,824'±7,844'±6,588'±6,608'21' T-73 ±7,963'±7,972'±6,724'±6,733'9' T-83 ±8,039'±8,054'±6,798'±6,813'16' T-90 ±8,177'±8,218'±6,933'±6,973'41' T-90 ±8,234'±8,244'±6,989'±6,999'10' T-90 ±8,256'±8,294'±7,011'±7,047'38' T-100 ±8,366'±8,389'±7,118'±7,140'23' T-115 ±8,462'±8,485'±7,211'±7,233'23' T-115 ±8,489'±8,519'±7,238'±7,267'30' T-140 ±8,731'±8,756'±7,475'±7,499'25' T-140 ±8,763'±8,791'±7,507'±7,534'28' Consult with OE for what WHP’s to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Matt Petrowsky (Geo): 814-421-6753 ii. Anthony McConkey (RE): 529-6199 6. RD E-Line Unit and turn well over to production. Existing and proposed perforations all lie within the Ninilchik Beluga/Tyonek Gas Pool defined in CO 701C. SFD 9/10/2021 Well: Kalotsa-04 Date: 9/10/2021 Cap String re-install Procedure: 1. RU Cap String Truck. 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve 250 psi low/3,500 psi high. 3. RIH with 3/8” capillary string to ±25’ MD above top open perf. Set cap string as deep as practical 4. Install slips and connect tubing to chemical injection pump. 5. Set spool of remaining line near well 6. RD cap string Unit and turn well over to production. Contingency EL Plug or Patch 7. MIRU E-line, PT lubricator to 250 psi low / 3,500 psi high 8. RIH W/ GPT tool and find fluid level 9. RU Nitrogen Truck a) Push water back into formation b) Use GPT tool to confirm water level is below interval to perf c) Consult OE for pressure to leave on well for perforating 10. Once fluid level is below interval to isolate, MU 4-1/2” patch or plug 11. RIH and set plug or patch per OE. 12. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations Updated by DMA 09-02-21 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 9,049’ / PBTVD = 7,789’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ JEWELRY DETAIL No. Depth ID OD Item 1 1,298’ 3.958” 6.875” Baker Swell Packer 2 9,054’ 4.500” CIBP w/ 5’ of cement 02/01/18 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 1,491’ 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958” Surf 9,213’ 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2” 6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows ToC = ~840’ MD PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T65 7,687’ 7,707’ 6,455’ 6,475’ 20’ 6 1/13/20 Open T80 7,984’ 7,995’ 6,745’ 6,755’ 11’ 6 06/21/19 Open T115 8,570’ 8,581’ 7,317’ 7,328’ 11’ 6 09/05/18 Open T115 8,583’ 8,596’ 7,330’ 7,343’ 13’ 6 10/12/18 Open T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 12/14/17 Open T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 11/23/17 Open T146 9,021’ 9,035’ 7,762’ 7,775’ 14’ 6 09/11/17 Open T146 9,037’ 9,045’ 7,777’ 7,785’ 8’ 6 08/31/17 Open T146 9,042’ 9,055’ 7,782 7,795 13’ 6 09/11/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/25/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/08/17 Isolated T146 9,072’ 9,080’ 7,811 7,819 8’ 6 09/11/17 Isolated T146 T142 2 TOF @ 9,061’ 01/31/18 Note: Fish @ 9,061’ 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIB T115 T80 T65 Capillary String (3/8”): 08-27-21 Top Bottom MD 0 7,400’ TVD 0 6,175’ 4-1/2" CBL indicates TOC at 1700' md. Update Schematic. Updated by CRR 09-10-21 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #4 PTD:217-063 API: 50-133-20665-00-00 PBTD = 9,049’ / PBTVD = 7,789’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ JEWELRY DETAIL No.Depth ID OD Item 1 1,298’3.958”6.875”Baker Swell Packer 2 9,054’4.500”CIBP w/ 5’ of cement 02/01/18 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 1,491’ 4-1/2"Prod Csg 12.6 L-80 DWC/C HT 3.958”Surf 9,213’ 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2”6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface.7/8/17 CBL shows ToC = ~840’ MD PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt SPF Date Status Perfs per sundry T65 7,687’7,707’6,455’6,475’20’6 1/13/20 Open T80 7,984’7,995’6,745’6,755’11’6 06/21/19 Open T115 8,570’8,581’7,317’7,328’11’6 09/05/18 Open T115 8,583’8,596’7,330’7,343’13’6 10/12/18 Open T142 8,843’8,862’7,585’7,604’19’6 12/14/17 Open T142 8,843’8,862’7,585’7,604’19’6 11/23/17 Open T146 9,021’9,035’7,762’7,775’14’6 09/11/17 Open T146 9,037’9,045’7,777’7,785’8’6 08/31/17 Open T146 9,042’9,055’7,782 7,795 13’6 09/11/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/25/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/08/17 Isolated T146 9,072’9,080’7,811 7,819 8’6 09/11/17 Isolated T146 T142 2 TOF @ 9,061’ 01/31/18 Note: Fish @ 9,061’ 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIBT115 T80 T65 Capillary String (3/8”):To be reinstalled Top Bottom MD 0 TBD TVD 0 TBD Existing and proposed perforations all lie within the Ninilchik Beluga/Tyonek Gas Pool defined in CO 701C. SFD 9/10/2021 4-1/2" CBL indicates TOC at 1700' md. Update Schematic on 10-404. 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 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: Cap String Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,221 feet 9,054 feet true vertical 7,958 feet 9,061 (fish) feet Effective Depth measured 9,049 feet 1,298 feet true vertical 7,789 feet 1,242 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 1,298' MD 1,242' 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 WINJ WAG 1,863 Water-Bbl MD 120' 1,491' 19 Oil-Bbl measured true vertical Packer 4-1/2"9,213'7,950' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ninilchik - Beluga/Tyonek Gas PoolN/A measured TVD Tubing Pressure 8117 Kalotsa 4 N/A (SHL) C061505 (TPH/BHL) ADL384372 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-063 50-133-20665-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-376 74 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 117 Authorized Signature with date: Authorized Name: 114 Casing Pressure Liner 1,689 0 Representative Daily Average Production or Injection Data 16' 1,491' 9,213' Conductor Surface Intermediate Production 7,500psi Casing Structural 16" 7-5/8" Length 6,890psi Collapse 1,410psi 4,790psi ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 2,980psi 8,430psi 120' 1,387' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 2:13 pm, Sep 10, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.10 14:02:31 -08'00' Taylor Wellman (2143) DSR-9/13/21 RBDMS HEW 9/10/2021 SFD 9/20/2021BJM 11/2/21 Rig Start Date End Date 8/26/21 8/27/21 PTW, JSA. Rig up capillary string truck loaded with 3/8" line. RIH and set string at 7,400'. Up weight 2,800 lbs. Leave 1500 on hydraulic pack off and manually lock down mechanical pack off. Rig down cap string truck. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Kalotsa 4 50-133-20665-00-00 217-063 08/26/2021 - Thursday Arrive on location, TBT to discuss spotting units. Spot units. Meet with Chad Ebenezer and sign work permit. Rig up .125" Slickline with 30' of 4-1/2" Lubricator c/w 4-1/2" Tool Trap c/w 4-1/2" Triple wireline valve c/w 4-1/2" PNT c/w 4-1/2" E12 X 4-1/2" Otis x-over on wellhead. Pressure test with Triplex pump to 300 PSI low test X 3 Minutes and 1,200 PSI High test X 5 Minutes. Test Good. Open swab valve 0 PSI on well. RIH with 1-7/8" Rope socket c/w 10' 1-7/8" Stem c/w 1-3/4" Hydraulic jars c/w 1-7/8" LSS C/W 3.72" Blind box to tag PBTD @ 9,038' slm + 18' KB= 9,056' RKB. POOH. At surface- close swab valve and bleed well to 0 PSI. Break out Blind box. Rigdown .125" Wire and 4-1/2" PCE. Proceed to Ninilchik State 1. Depart location and proceed to Ninichik State 1 well. 08/27/2021- Friday Rig up capillary string truck loaded with 3/8"line. RIH and set string at 7,400' Updated by DMA 09-02-21 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00-00 PBTD = 9,049’ / PBTVD = 7,789’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ JEWELRY DETAIL No. Depth ID OD Item 1 1,298’ 3.958” 6.875” Baker Swell Packer 2 9,054’ 4.500” CIBP w/ 5’ of cement 02/01/18 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 1,491’ 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958” Surf 9,213’ 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2” 6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. 7/8/17 CBL shows ToC = ~840’ MD PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T65 7,687’ 7,707’ 6,455’ 6,475’ 20’ 6 1/13/20 Open T80 7,984’ 7,995’ 6,745’ 6,755’ 11’ 6 06/21/19 Open T115 8,570’ 8,581’ 7,317’ 7,328’ 11’ 6 09/05/18 Open T115 8,583’ 8,596’ 7,330’ 7,343’ 13’ 6 10/12/18 Open T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 12/14/17 Open T142 8,843’ 8,862’ 7,585’ 7,604’ 19’ 6 11/23/17 Open T146 9,021’ 9,035’ 7,762’ 7,775’ 14’ 6 09/11/17 Open T146 9,037’ 9,045’ 7,777’ 7,785’ 8’ 6 08/31/17 Open T146 9,042’ 9,055’ 7,782 7,795 13’ 6 09/11/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/25/17 Isolated T146 9,056’ 9,076’ 7,795 7,815 20’ 6 08/08/17 Isolated T146 9,072’ 9,080’ 7,811 7,819 8’ 6 09/11/17 Isolated T146 T142 2 TOF @ 9,061’ 01/31/18 Note: Fish @ 9,061’ 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIB T115 T80 T65 Capillary String (3/8”): 08-27-21 Top Bottom MD 0 7,400’ TVD 0 6,175’ 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: ______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? 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): 9,221'9,061' (fish) Casing Collapse Structural Conductor 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 ryan.rupert @hilcorp.com 7,958'9,049'7,789'~2,725 psi 9,054' Baker Swell Packer; N/A 1,298' MD/1,242' TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 C061505 (SHL) / ADL384372 (BHL) 217-063 50-133-20665-00-00 Kalotsa 4 Ninilchik Field - Beluga/Tyonek Gas Pool Length Size CO 701C Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 8,430psi MD 6,890psi 120' 1,387' 120' 1,491' 7,950'4-1/2" 16" 7-5/8" 120' 1,491' 9,213' Perforation Depth MD (ft): See Attached Schematic 9,213' 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: August 13, 2021 N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 11:46 am, Jul 29, 2021 321-376 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.07.29 09:29:46 -08'00' Taylor Wellman (2143) 10-404 DLB 07/29/2021BJM 8/2/21 DSR-7/29/21 X dts 8/2/2021 JLC 8/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.02 11:07:59 -08'00' RBDMS HEW 8/3/2021 Cap String Well: Kalotsa-04 Date: 7/29/2021 Well Name:Kalotsa-04 API Number:50-133-20665-00-00 Current Status:Producing Gas Well Permit to Drill Number:217-063 Regulatory Contact:Donna Ambruz (907) 777-8305 (O) First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (M) Second Call Engineer:Ted Kramer (907) 777-8420 (O)(985) 867-0665 (M) Maximum Expected BHP:~ 3504 psi @ 7785’ TVD (Based on a 0.45 psi/ft. gradient) Max. Potential Surface Pressure:~ 2725 psi (Using Max BHP minus 0.1 psi/ft. gas gradient to surface). Brief Well Summary Kalotsa-04 has been a steady gas producer at >1.5MMCFD for the past year. The well has been making 15- 25bwpd. It has been requiring multiple soap sticks each day and has fallen off to <500mcf a few times recently. The purpose of this work/sundry is to install a Capillary String in the well to allow for soap to be injected to help unload water. Notes Regarding Wellbore Condition x Max inclination = 55deg at 1748’ MD x Drifts o 1/13/20: EL made it to 7707’ MD with a 20’ x 2-7/8” perf gun and logging sub while SI o 6/21/19: EL made it to 7995’ MD with a 15’ x 2-7/8” perf gun and logging sub while flowing Procedure: 1. RU Cap String Truck. 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve 250 psi low/3,500 psi high. 3. RIH with 3/8” capillary string to ±7650’ MD. 4. Install slips and connect tubing to chemical injection pump. 5. Set spool of remaining line near well 6. RD cap string Unit, and turn well over to production. Attachments: 1. Proposed Schematic Updated by CRR 7-29-21 SCHEMATIC Ninilchik Unit Kalotsa #4 PTD:217-063 API: 50-133-20665-00 PBTD = 9,049’ / PBTVD = 7,789’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120' 7-5/8"Surf Csg 29.7 L-80 BTC 6.875”Surf 1,491’ 4-1/2"Prod Csg 12.6 L-80 DWC/C HT 3.958”Surf 9,213’ 1 16” 7-5/8” 6-3/4” Hole 4-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 1,298’3.958”6.875”Baker Swell Packer 2 9,054’4.500”CIBP w/ 5’ of cement 02/01/18 RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2”6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface.7/8/17 CBL shows ToC = ~840’ MD PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt SPF Date Status T65 7,687’7,707’6,455’6,475’20’6 1/13/20 Open T80 7,984’7,995’6,745’6,755’11’6 06/21/19 Open T115 8,570’8,581’7,317’7,328’11’6 09/05/18 Open T115 8,583’8,596’7,330’7,343’13’6 10/12/18 Open T142 8,843’8,862’7,585’7,604’19’6 12/14/17 Open T142 8,843’8,862’7,585’7,604’19’6 11/23/17 Open T146 9,021’9,035’7,762’7,775’14’6 09/11/17 Open T146 9,037’9,045’7,777’7,785’8’6 08/31/17 Open T146 9,042’9,055’7,782 7,795 13’6 09/11/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/25/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/08/17 Isolated T146 9,072’9,080’7,811 7,819 8’6 09/11/17 Isolated T146 T142 2 TOF @ 9,061’ 01/31/18 Note: Fish @ 9,061’ 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIB T115 T80 T65 Updated by CRR 7-29-21 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa #4 PTD:217-063 API: 50-133-20665-00 PBTD = 9,049’ / PBTVD = 7,789’ TD = 9,221’ / TVD = 7,958’ RKB to GL = 18’ JEWELRY DETAIL No.Depth ID OD Item 1 1,298’3.958”6.875”Baker Swell Packer 2 9,054’4.500”CIBP w/ 5’ of cement 02/01/18 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 1,491’ 4-1/2"Prod Csg 12.6 L-80 DWC/C HT 3.958”Surf 9,213’ 1 16” 7-5/8” 6-3/4” Hole 4-1/2” RA @ 5,490’ RA @ 6,490’ RA @ 7,500’ RA @ 8,496’ OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8” hole. 100 BBL of 12 ppg Type I/II lead and 39.5 BBLs 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 4-1/2”6-3/4” hole. 240 bbls 12.2 Type I/II and 35.2 bbls 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface.7/8/17 CBL shows ToC = ~840’ MD PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt SPF Date Status T65 7,687’7,707’6,455’6,475’20’6 1/13/20 Open T80 7,984’7,995’6,745’6,755’11’6 06/21/19 Open T115 8,570’8,581’7,317’7,328’11’6 09/05/18 Open T115 8,583’8,596’7,330’7,343’13’6 10/12/18 Open T142 8,843’8,862’7,585’7,604’19’6 12/14/17 Open T142 8,843’8,862’7,585’7,604’19’6 11/23/17 Open T146 9,021’9,035’7,762’7,775’14’6 09/11/17 Open T146 9,037’9,045’7,777’7,785’8’6 08/31/17 Open T146 9,042’9,055’7,782 7,795 13’6 09/11/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/25/17 Isolated T146 9,056’9,076’7,795 7,815 20’6 08/08/17 Isolated T146 9,072’9,080’7,811 7,819 8’6 09/11/17 Isolated T146 T142 2 TOF @ 9,061’ 01/31/18 Note: Fish @ 9,061’ 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIBT115 T80 T65 Capillary String (3/8”):To be run Top Bottom MD 0 7,650’ TVD 0 6,419’ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 2 4 2020 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li ADGUGown Ll Performed: Suspend ❑ Perforate 2 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redn[l ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 217-063 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20665-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: (SHL) C061505 (TPH/BHL) ADL384372 Kalotsa 4 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik - Beluga/Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,221 feet Plugs measured 9,054 feet true vertical 7,958 feet Junk measured 9,061 (fish) feet Effective Depth measured 9,049 feel Packer measured 1,298 feet true vertical 7,789 feet true vertical 1,242 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 16' 16" 120' 120' 2,980psi 1,410psi Surface 1,491' 7-5/8" 1,491' 1,387' 6,890psi 4,790psi Intermediate Production 9,213' 4-1/2" 9,213' 7,950' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker Swell Pkr 1,298' MD 1,242' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf/1ater-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 50 2 127 41 Subsequent to operation: 0 13609 1 113 945 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.293) 15. Well Class after wokk. Daily Report of Well Operations Q Exploratory❑ Devetopment0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 320-013 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(a)hilcoro.com Authorized Signature: Date: 2-11 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 d ,/ �� /'. '7 p, 8��5 I�Eu/ JAN 2 7 2020 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 1 50-133-20665-00 217-063 1/13/20 1/13/20 Daily Operations: 01/13/2020 - Monday Sign in. PTW and JSA. Spot and rig up equipment. Attempt to pressure test lubricator and had o-ring leak at top. Drained and laid down lub. Replace o-ring and PT lubricator to 250 psi low and 3,000 psi high. RIH w/GPT tool and tie into OHL. Tag plug at 9,054'. Found soapy/gas cut fluid on bottom but found no solid fluid level. Run correlation log and send to town. POOH RIH w/ 2-7/8" x 2' HC Razor, 6 spf, 60 deg phase pert gun and tie into OHL. Run correlation log and send to town. Get ok to perforate from 7,695' to 7,697' with 515 psi on well. Spotted and fired gun. After 5 min - 847 psi, 10 min - 982.5 psi and 15 min - 1,018.6 psi. POOH. All shots fired and gun was dry. RIH w/ 2-7/8" x 20' HC Razor, 6 spf, 60 deg phase perf gun and tie into OHL. Run correlation log and send to town. Get ok to perforate from 7 687' to 7 707' with 994.4 psi on well. Spotted and fired gun. After 5 min - 1,166 psi, 10 min - 1,198.5 psi and 15 min - 1,213.1 psi. POOH. All shots fired and gun was dry. Rig down lubricator and equipment. Turn well back over to field. 16" Ninilchik Unit SCHEMATIC Kalotsa #4 PTD: 217-063 Hileury Aleeka, l.LC API: 50-133-20665-00 RKB to GL = 18' f'ASINr nFTAII 'I Type Wt Grade Conn. I V/ 3/4" Hale I RA @ 5,490' • ' a RA @ 6,490' ,i RA @ 7,500' w l_ T65 T80 RA @ 8,496' • • • T115 T142 TaF @ 9,061' 09/31/18 21 T146 4-1/2" PBTD = 9,049'/ PBTVD = 7,789' TO = 9,221'/TVD = 7,958' Size Type Wt Grade Conn. ID Top I Btm A Conductor -Driven to Set Depth 84 %-56 Weld 15.01" 1 120' 7-5/8" }rl a5/x" L-80 BTC V/ 3/4" Hale I RA @ 5,490' • ' a RA @ 6,490' ,i RA @ 7,500' w l_ T65 T80 RA @ 8,496' • • • T115 T142 TaF @ 9,061' 09/31/18 21 T146 4-1/2" PBTD = 9,049'/ PBTVD = 7,789' TO = 9,221'/TVD = 7,958' Size Type Wt Grade Conn. ID Top I Btm 16" Conductor -Driven to Set Depth 84 %-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958" Surf 9,213' JEWELRY DETAIL No. Depth ID OD Item 1 1 1,298' 3.958" 6.875" Baker Swell Packer 2 1 9,054' 4.500" CIBP w/5' of cement 02/03/18 PERFORATIONS Zone Top(MD) Btm(MD) T0p(TVD) Btm(TVD) Amt SPF Date status T65 7,687' 7,707' 6,455' 6,475' 20' 6 1/13/20 Open T80 7,984' 7,995' 6,745' 6,755' 11' 6 06/21/19 Open T115 8,570' 8,581' 7,317' 7,328' 11' 6 09/05/18 Open T115 8,583' 8,596' 7,330' 7,343' 13' 6 10/12/18 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 12/14/17 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 11/23/17 Open T146 9,021' 9,035' 7,762' 7,775' 14' 6 09/11/17 Open T146 9,037' 9,045' 7,777' 7,785' 8' 6 08/31/17 Open T146 9,042' 9,055' 7,782 7,795 13 6 09/11/17 Isolated T146 9,056' 9,076' 7,795 7,815 20' 6 08/25/17 Isolated T146 9,056' 9,076' 7,795 7,815 20' 6 08/08/17 Isolated T146 9,072' 9,080' 7,811 7,819 8' 6 09/11/17 Isolated OPEN HOLE /CEMENT DETAIL 7-5/8" 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/11 lead and 39.5 BBLs (1815x) 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4-1/2" 6-3/4" hole. 240 bbls (675sx) 12.2 Type 1/II and 35.2 bbls (160 sx) 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. Est. TOC±338' MD. Note: Fish @ 9,061'01/31/18 consists of: Weatherford W RP w/ catcher sub, wire and LIB Updated by DMA 01-23-20 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 10 2020 1. Operations Abandon L Plug Perforations Fracture Stimulate Pull Tubing at s hutdown LJ Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casin g ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 217-063 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20665-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: (SHL) C061505 (TPH/BHL) ADL384372 Kalotsa 4 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik- Beluga/Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,221 feet Plugs measured 9,054 feet true vertical 7,958 feet Junk measured 9,061 (fish) feet Effective Depth measured 9,049 feet Packer measured 1,298 feet true vertical 7,789 feet true vertical 1,242 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 16' 16" 120' 120' Surface 1,491' 7-5/8" 1,491' 1,387' 6,890psi 4,790psi Intermediate Production 9,213' 4-1/2" 9,213' 7,950' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker Swell Pkr 1,298' MD 1,242' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1058 2 182 194 Subsequent to operation: 0 1167 3 177 228 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ✓ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-286 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(olhilcoro.com Authorized Signature: Date: 1 I's 4" Z t.1 rn Contact Phone: 777-8420 Form 10-404 Revised 4/2017 f /�Ox �iL. �, s".Z (7 RBDMS� SAN 13 2020 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 50-133-20665-00 217-063 6/21/20 1 6/21/20 Daily Operations: 6/21/2019 - Friday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,500 psi high RIH with GPT tool, tie into OHL and tag at 9,054'. Could not find solid fluid level but could see some fluid coming out of the T142 sand around 8,850'. Ran log and send to town. Well flowing 1.02 million at 185. RIH/ 2-7/8" Razor HC, 6 spf, 60 deg phase to around 3000' and gamma ray quit working. POOH. Extra gun gamma had bad threads. Waited for another gun gamma to be brought out. Put new gun gamma on and went in hole with same perf gun and tie into OHL. Ran correlation log and send to town. Get ok to perf from 7,984' to 7,995'. Spotted and fired gun at 1540 hrs w/well flowing 1.027 mmcf at 1.84 psi.. 5 min - 1.569 mmcf at 205 psi. 10 min - 1.691mmcf at 211 psi and 15 min -1.811 mmcf at 219 psi. POOH Rig down lubricator and turn well over to field. Ninilchik Unit SCHEMATIC Kalotsa #4 PTD: 217-063 Hflauep Alen4a,1LC API: 50-133-20665-00 RKB to GL= 18' 16" V. _1 v a 1 7-5/8" }} A' 6-3/4" Hole �! RA @ 5,490' a0, 9 l4, RA @ 6,490' A RA @ 7,500' r • '41 f T80 RA @ 8,496' a • T115 T142 TOF @ 9,061' of13VIS JJ21 T146 4-1/2" PBTD = 9,049'/ PBTVD = 7,789' TD = 9,221'/ ND = 7,958' rACINr hFTAII Size Type Wt Grade Conn. ID Top Btm 16" Conductor -Driven to Set Depth 84 %-56 Weld 15.01" Surf120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875 Surf 1,491' 4-1/2" Prod Csg 12.6 L-80 DWC/C H7 3.958" Surf 9,213' JEWELRY DETAIL No. Depth ID OD Item 1 I 1,298' 1 3.958" 6.875" 1 Baker Swell Packer 2 j 9,054' 1 4.500" 1 CIBP w/5'of cement 02/01/18 PERFORATIONS Zone Top(MD)q D) Top(NP (TVD) Amt SPF Date Status T80 7,984'' 6,7455' 11' 6 06/21/19 Open T115 8,570'' 7,31328' 11' 6 09/05/18 Open T115 8,583' ' 7,3343' 13' 6 10/12/18 Open T142 8,843' ' 7,5804' 19' 6 12/14/17 Open T142 8,843' ' 7,5804' 19' 6 11/23/17 Open T346 9,021' ' 7,7675' 14 6 09/11/17 Open T146 9,037' ' 7,7785' 8' 6 8/31/1T146 9,042' ' 7,78795 13' 6 09/11/17 Isolated T146 9,056' ' 7,79815 20' 6 08/25/17 Isolated T146 9,056' 7,79815 20' 6 08/08/17olated T146 9,072' ' 7,8119 8' 6 09/11/17 Isolated OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type VII lead and 39.5 BBLs (181sx) 15.4 ppg Class G tail. 100% returns throughout, 11111, of lead to surface. 5/14/17 4-1/2" 6-3/4" hole. 240 bbls (675sx) 12.2 Type 1/11 and 35.2 bbls (160 sx) 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. Est. TOC ±338' MD. Note: Fish @ 9,061' 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIB Updated by DMA 01-10-20 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 4 Permit to Drill Number: 217-063 Sundry Number: 320-013 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.aIaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, DATED this today of January, 2020. RBDMS JAN 13 20n STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 13, 2020 APPLICATION FOR SUNDRY APPROVALS / j o (Zo ors 20 AAC 25.280 A r%d' . r% f% 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ p ti s shutdown ❑ Suspend ❑ Perforate Q • 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: Hilcorp Alaska, LLC Exploratory ❑ Development Q . Stratigraphic ❑ Service ❑ 217-063 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20665-00-00 - 7. If perforating: �`^, 'rj0%r� 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 'XC' Will planned perforations require a spacing exception? Yes El No ❑✓ , ` /r`J , Kalotsa 4 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ' C061505 (SHL) / ADL384372 (BHL)- Ninilchik Field - Beluga/Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,221' - 7,958' 9,049' 7,789' —1,800 psi 9,054' 9,061' (fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,491' 7-5/8" 1,491' 1,387' 6,890psi 4,790psi Intermediate Production 9,213' 4-1/2" 1 9,213' 1 7,950' 1 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 I N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Swell Packer; N/A 1,298' MD/1,242' TVD; N/A 12. Attachments: Proposal Summary 21 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: January 13, 2020 . OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ • WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer hllcof .Com Contact Phone: 777-8420 Authorized Signature: Date: J6 Gh Lo Zo COMMISSION USE ONLY �/ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: // �O _ 0/ Plug Integrity El BOP BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: RBDMS14P JAN 13 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing 0�hphon Required? ❑ No Subsequent Form Required: 0 + THEAPPROVEDS Approved by: COMMISSIONER THE COMMMM ISSION Date: R /U,40 %/� ��fr,_yc 11D�1_IA /%®% ubmil Form ond Form 10- 3 Revis 17 Approved application is vol oltVfRs 1Fr Il�Jla of approval. Attachments in Duplicate H Haeorp Alaska, LL, Well Prognosis Well: Kalotsa #4 Date: 1/10/2020 Well Name: Kalotsa #4 API Number: 50-133-20665-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: January 13th, 2020 Rig: E -line Reg, Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-063 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Cristina Twogood (907) 777-8443 (0) (907) 378-7323 (M) AFE Number: Maximum Expected BHP: -- 2,000 psi @ 6,505' TVD (Based on flowing P/Z data ) Max. Potential Surface Pressure: — 1,800 psi @ 6,505' TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary Kalotsa #4 is a gas producer that is currently open and producing in the T-80, T-115, T142 and T146 sands at a rate of 750 Mcfd. The purpose of this work/sundry is to add the T-65 sand. Notes Regarding Wellbore Condition • A CBL ran July 8, 2017 shows excellent cement covering the T-65 sand. • Well will be shut in the day of the Job to minimize downtime. Safety Concerns • Consider wind direction and current weather forecast in rigging up Unit. Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU e -line and pressure control equipment. PT lubricator to 3,000 psi Hi 250 Low. 2. Run GPT tool to determine the fluid level (if any). 3. Shut in well and document shut in tubing pressure. Run in well with perfguns and pressure up well to 750 psi. with offset gas. 4. Perforate the T-65 Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns (up to 12 SPF with 2 pert runs). Note: First Run Maybe a 2' gun to Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Tyonek T65 ±7,684' ±7,737' 1 ±6,452' ±6,505' 53' a. Proposed perfs also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. 0 Hikorn Alaska, LLi 5. POOH. Well Prognosis Well: Kalotsa #4 Date: 1/10/2020 Rule 2 of Conservation Order -7.09A defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of-t,48A trthe Pa�ctrnr bra tlae Ra3etert 9�vetl— /s S3 '/v %D'3S �- 4� /,p ✓lh 3 6. RD a -line. E -line Procedure (Contingency): 1. If this zone produces sand and/or water or needs isolated 2. M I R U E -line, PT lubricator to 3,500 psi Hi 250 Low. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic i& /.io- 2 -r ->l RKB to GL= 18' • t :6 �pI 1 7-5/8" ' • •� a • �rYr� 6 3/4" Hole RA @ 5,490' �• RA @ 6,490' e a RA @ 7,500' • Type {{ Grade Conn. ID Top Btm 16" Conductor -Driven to Set Depth 84 T80 RA @ 8,496' s 15.01" Surf 120' 7-5/8" Surf Csg 29.7 T115 BTC 6.875" Surf T142 G�!1 Prod Csg 12.6 L-80 TOF @ 9,061' 3.958" Surf 9,213' 01/31/18 - ' - a 10/12/18 2T146 T142 i^ r: 4-1/2" '- 8,862' - 7,585' 7,604' PBTD = 9,049'/ PBTVD = 7,789' 6 TD = 9,221'/ TVD = 7,958' Open SCHEMATIC CASING DETAIL Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00 Size Type Wt Grade Conn. ID Top Btm 16" Conductor -Driven to Set Depth 84 X-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' 4-1/2" Prod Csg 12.6 L-80 DWC/CHT 1 3.958" Surf 9,213' JEWELRY DETAIL No. Depth ID OD Item 1 1,298' 3.958" 6.875" Baker Swell Packer 2 9,054' 4.500" CIBP w/5' of cement 02/01/18 IJyt77117eLAifiTJC9 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T80 7,984' 7,995' 1 6,745' 6,755' 11' 6 06/21/19 Open T115 8,570' 8,581' 7,317' 7,328' 11' 6 09/05/18 Open T115 8,583' 8,596' 7,330' 7,343' 13' 6 10/12/18 Open T142 8,843' 8,862' - 7,585' 7,604' 19' 6 12/14/17 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 11/23/17 Open T146 9,021' 9,035' 7,762' 7,775' 14' 6 09/11/17 Open T346 9,037' 9,045' - 7,777' 7,785' 8' 6 08/31/17 Open T146 9,042' 9,055" 7,782 7,795 13' 6 09/11/17 Isolated T346 9,056' 9,076' 7,795 7,815 20' 6 08/25/17 Isolated T146 9,056' 9,076' 7,795 7,815 20' 6 1 08/08/17 Isolated T146 9,072' 9,080' ' 7,811 7,819 8' 6 09/11/17 Isolated OPEN HOLE/ CEMENT DETAIL 7-5/811 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/11 lead and 39.5 BBLs (181sx) 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4-1/2" 6-3/4" hole. 240 bbls (675sx) 12.2 Type 1/II and 35.2 bbls (160 sx) 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. Est. TOC ±338' MD. Note: Fish @ 9,061' 01/31/18 consists of: Weatherford W RP w/ catcher sub, wire and LIB Updated by DMA 01-10-20 Ninilchik Unit PROPOSED SCHEMATIC KaloPTD: t2174063 API: 50-133-20665-00 Flileoep AIueW,Id.0 RKB to GL= 18' 16" V ` 7-5/8" - d 7 i 4' 4 L 9' It t� 6-3/4" Hole i - RA @ 5,490' RA @ 6,490' A RA @ 7,500' s RA @ 8,496' ♦ 6 A TOF @ 9,061' 01/31/18 1 r F. 4-1/2" PBTD = 9,049' / PBTVD = 7,789' TD = 9,221'/ TVD = 7,958' T65 T80 T115 T142 21 T146 rArwr r1FTAll Size Type Wt Grade Conn. ID Top Btm 16" Conductor -Driven 84 to Set Depth X-56 Weld 15.01" Surt 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' 4-1/2" Prod Csg 12.6 L-80 DWC/CHT 3.958" Surf 9,213' JEWELRY DETAIL N Top(MD) Btm(MD) Item Btm(TVD) 1, .9ID58"OD 6.875" BakerSwell Packer 2 1 9,054' 4.500" CIBP w/5'of cement 02/01/18 PFRFC)RATinNS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date status T65 ±7,684' ±7,737' ±6,452' ±6,504' ±53' 6 Proposed TBD T80 7,984' 7,995' 6,745' 6,755' 11' 6 06/21/19 Open T115 8,570' 8,581' 7,317' 7,328' 11' 6 09/05/18 Open T115 8,583' 8,596' 7,330' 7,343' 13' 1 6 1 10/12/18 Open T142 8,843' 8,862' 7,585' 7,604' 19'6 12/14/17 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 11/23/17 Open T146 9,021' 9,035' 7,762' 7,775' 14' 6 09/11/17 Open T146 9,037' 9,045' 7,777' 7,785' 8' 6 08/31/17 Open T146 9,042' 9,055' 7,782 7,795 6 09/11/17 Isolated T146 9,056' 9,076' 7,795 7,815 6 08/25/17 Isolated T146 9,056' 9,076' 7,795 7,815 !220' 6 08/08/17 Isolated 9,072' 9080' 7811 7,819 6 09/11/17 Isolated OPEN HOLE / CEMENT DETAIL 7-5/8" 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/II lead and 39.5 BBIs (181sx) 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4-1/2" 6-3/4" hole. 240 bbls (675sx) 12.2 Type 1/11 and 35.2 bbls (160 5x)15.3 ppg Class G '-;1. 100% returns. Trace volume of spacer to surface. Est. TOC 11338' MD. Note: Fish @ 9,061' 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIB Updated by DMA 01-30-20 Schwartz, Guy L (CED) From: Bo York <byork@hilcorp.com> Sent: Friday, January 10, 2020 11:45 AM To: Schwartz, Guy L (CED) Cc: Holly Tipton; Christina Twogood - (C); Ted Kramer Subject: Hilcorp Expedited Sundry Requests - Gas Well Perforations Guy - Three sundries are being submitted to you today (10 January) for perforations to existing Kenai gas wells. The three sundries are: • Kalotsa 4 o T65 — 7684' — 7737' M D • Paxton 3 o BEL-10-2740'-2877'MD o BEL-13-2970'-3045'MD o BEL -16-3150'-3340' MD o BEL -20-3528'-3637' MD • Paxton 4 o BEL -10-2770'-2900' MD o BEL-13-2964'-3080'MD o BEL-16-3240'-3340'MD o BEL -20-3489'-3540' MD We are asking for expedited review due to the current cold snap and market conditions. As we discussed yesterday on the phone, south central AK is pulling—340MMscf of gas right now (this is my estimate). Hilcorp in the inlet is delivering —100MMscf from our storage wells and another-110MMscf from base production. CINGSA I heard this morning is delivering 120MMscf. Hilcorp has been producing at this unusually high rate since 10 Dec when Enstar started a "test' of our deliverability. The test has officially ended but it has been more than replaced by the actual cold weather. The current cold snap is expected to continue another 10 days and our customers have already notified us they are going to be needing our current volumes through at least 20 January. Our objective with these pert adds is to protect our storage volumes as much as possible to ensure we keep them pressured up in case the cold continues or returns later in the winter. It is only 10 January and we have a lot of winter left. These perfs in these three wells are expected to bring on immediate and significant base rate which will help protect our storage volumes as well as CINGSA volumes. I appreciate any support you can provide in approving these in an expedited manner. Feel free to call to discuss further. Bo York Hilcorp Alaska LLC Kenai Operations Manager byork@Hilcorp.com 907.777.8345 907.727.9247 cell The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 4 Permit to Drill Number: 217-063 Sundry Number: 319-286 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 2ss6,A—, il� ie� / ielowski Commissioner DATED this 12- day of June, 2019. ROWS' JUN 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RiECEIIVED JUN 07 2019 /tq L/t V ( 7 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: Hilcorp Alaska, LLC Exploratory ❑ Development Q Strati ra hic g p ❑ Service ❑ 217-063 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: � Anchorage Alaska 99503 50-133-20665-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Kalotsa 4 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): C061505 (SHL) / ADL384372 (BHL) Ninilchik Field - Beluga/ryonek Gas Pool ` it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (it): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,221' 7,958' 9,049' 7,789' -2,170 psi 9,054' 9,061' (fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 1,491' 7-5/8" 1,491' 1,387' 6,890psi 4,790psi Intermediate Production 9,213' 4-1/2" 1 9,213' 7,950' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (it): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (it): Baker Swell Packer; N/A 1,298' MD/1,242' TVD; N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: June 24, 2019 Operations: OIL E]WINJ ❑ WDSPL E] Suspended 1-1Commencing GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 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. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkrafller hilcor .com Contact Phone: 777-8420 Authorized Signature: Date: 7 J .r'.. Lp1 ` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I q 12 o Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ppp 'fit Post Initial ±JUN 13 2019 Injection MIT Req'd? Yes E] No F-1RB�MrJ Spacing Exception Required? Yes ❑ No Subsequent Form Required: ` APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:2�1 6T �! �� Submit Form and Form 10-403 Revised 4/2077 Ap v d ppli 1 m the date of approve . Attachments in Duplicate U Hilwrp Alaska, LL Well Prognosis Well: Kalotsa #4 Date: 6/7/2019 Well Name: Kalotsa #4 API Number: 50-133-20665-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: June 24th, 2019 Rig: E -line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-063 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Maximum Expected BHP Max. Potential Surface Pressure: Brief Well Summary — 2,905 psi @ 6,755' TVD —2,170 psi @ 7,347' TVD (Based on normal gradient of 0.43 psi/ft and the lowest perforation) (Based on expected BHP and gas gradient to surface (0.10psi/ft) Kalotsa #4 is a gas producer that is currently open and producing in the T-115, T142 and T146 sands at a rate of 1.2 MMcfd. ' The purpose of this work/sundry is to add the T-80 sand. X Notes Regarding Wellbore Condition • A CBL ran July 8, 2017 shows excellent cement covering the T-80 sand. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) • Ensure all crews are aware of stop job authority E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. 2. Run GPT tool to determine the fluid level (if any). 3. Pressure upon well to push fluid level below 8,000'. (Note: Nitrogen maybe used to pressure ap/ well.) Pressure up well to 1,700 psi. With either off set gas or nitrogen. 4. Perforate the T-80 Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns (up to 12 SPF with 2 pert runs) Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Tyonek T80 ±7,984' ±7,995' ±6,745' ±6,755' 11' a. Proposed perfs also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. H nile.wo M.A.. LL, Well Prognosis Well: Kalotsa #4 Date: 6/7/2019 d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. Rule 2 of Conservation Order 701A defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. 5. POOH. 6. RD e -line. E -line Procedure (Contingency): 1. If this zone produces sand and/or water or needs isolated 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 3. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure— N2 Operations Ninilchik Unit SCHEMATIC Kalotsa #4 11 PTD: 217-063 In4orp AIaeW, LLC API: 50-133-20665-00 ll to GL=18' 16" &A 7 7-5/8" I. L 6-3/4" Hole A 4. RA @ 5,490' ®� RA @ 6,490' RA @ 7,500' A! RA @ 8,496' ° s • TOF@9,061' 01/31/13 ' 4-1/2" . �.� 'k ` -- PBT/ = 9,049'/ PBTVD = 7,789' TO = 9,221'/ TVD = 7,958' T115 T142 21 T146 CASING DETAIL Size Type Wt Grade Conn. ID Top I Btm 16" Conductor- Driven to Set Depth 84 X-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958" Surf 9,213' JEWELRY DETAIL No. Depth ID OD Item 1 1,298' 3.958" 6.875" Baker Swell Packer 2 9,054' 4.500" 1 CIBP w/5'of cement 02/01/18 I]y:77�7:73iriTP C9 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T315 8,570' 8,581' 7,317' 7,328' 11' 6 09/05/18 Open T115 8,583' 8,596' 7,337 7,343' 13' 6 10/12/18 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 12/14/17 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 11/23/17 Open T146 9,021' 9,035' 7,762' 7,775' 14' 6 09/11/17 Open T146 9,037' 9,045' 7,777' 7,785' 8' 6 08/31/17 Open T146 9,042' 9,055' 7,782 7,795 13' 6 09/11/17 Isolated T146 9,056' 9,076' 7,795 7,815 20' 6 08/25/17 Isolated T146 9,056' 9,076' 7,795 7,815 20' 6 21/08/17 Isolated T146 9,072' 9,087 7,811 7,819 8' 6 09/11/17 Isolated OPEN HOLE / CEMENT DETAIL 7-5/811 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/II lead and 39.5 BBLs (181sx)15,4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4 1/2" 6-3/4" hole. 240 bbis (675sx) 12.2 Type I/II and 35.2 bbls (160 sx)15,3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. Est. TOC±338' MD. Note: Fish @ 9,061' 01/31/18 consists of: Weatherford W RP w/ catcher sub, wire and LIB Updated by DMA 10-24-18 K wrp Abake, l.LC RKB to GL = 18' 16" .93 7-S/8" i •1i PROPOSED SCHEMATIC :}a t� tee, 1 CASING DETAIL Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00 Size Type Wt I Conn. ID Top Btm 16" Conductor -Driven to Set Depth 6 3/4" X-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' 4-1/2" RA @ 5,490' 4Al L-80 DWC/CHT 3.958" Surf 9,213' 13' 6 10/12/18 RA @ 6,490' e` 8,843' 8,862' 7,585' RA @ 7,500' 19' 6 12/14/17 Open T142 8,843' 8,862' 7,585' T80 RA @ 8,496' ®° 11/23/17 Open T146 9,021' 9,035' 7,762' 7,775' T115 6 v Open T146 T142 TOF@9,061' 7,777' 7,785' 8' 6 01/31/18 Open T146 9,042' T346 7,782 4-1/2" 13' 6 09/11/17 Isolated PBTD = 9,049'/ PBTVD = 7,789' 9,076' 7,795 TD = 9,221' / TVD = 7,958' 20' CASING DETAIL Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00 Size Type Wt Grade Conn. ID Top Btm 16" Conductor -Driven to Set Depth 84 X-56 Weld 15.01" Surf 120' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' 4-1/2" Prod Csg 12.6 L-80 DWC/CHT 3.958" Surf 9,213' IIyTITMIlY B No. Depth ID OD Item 1 1,298' 3.958" 6.875" Baker Swell Packer 2 1 9,054' ±6,745' 1 4.500' 1 CIBP w/5'of cement 02/01/18 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T80 ±7,984' ±7,995' ±6,745' ±6,755' ±11' 6 Proposed TBD T115 8,570 8,581' 7,317' 7,328' 11' 6 09/05/18 Open T115 8,583' 8,596' 7,330' 7,343' 13' 6 10/12/18 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 12/14/17 Open T142 8,843' 8,862' 7,585' 7,604' 19' 6 11/23/17 Open T146 9,021' 9,035' 7,762' 7,775' 14' 6 09/11/17 Open T146 9,037' 9,045' 7,777' 7,785' 8' 6 08/31/17 Open T146 9,042' 9,055' 7,782 7,795 13' 6 09/11/17 Isolated T146 9,056' 9,076' 7,795 7,815 20' 6 08/25/17 Isolated T146 9,056' 9,076' 7,795 7,815 20' 6 08/08/17 Isolated T146 9,072' 1 9,080' 7,811 1 7,819 1 8' 6 09/11/17 Isolated OPEN HOLE / CEMENT DETAIL 7 5/8" 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/11 lead and 39.5 BBIs (1815x)15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4-1/2" 6-3/4" hole. 240 bbls (675sx) 12.2 Type 1/11 and 35.2 bbls (160 sx)15,3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. Est. TOC ±339' MD. Note: Fish @ 9,061' 01/31/18 consists of: Weatherford WRP w/ catcher sub, wire and LIB Updated by DMA 06-07-19 STANDARD WELL PROCEDURE Hilcorp Alaska, LLA: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINALvl Page 1 of 1 DATE 3/27/2019 Debra _udean GeoTech Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To. Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 Tiv RECEIVED MAR 282019 AOGCC PERFORATION RECORD 5 SEP 2018 & 12 OCT 2018 PERF 5 SEP 18 i KALOTSA_4_PERF 05SEP18 11113/201810:03 ... PDF Document 851 KB KALOTSA4_PERF_05SEPI8_Correlation 11/13/2013 1 0:2{3 ... LAS File 531 KB FWKALOTSA 4_PERF_05SEP18_img 11113/2D18 10:03... TIFF File 1,198 KB KALOTSA_4_PERF 05SEP18_PERF 8570-85... 11/131-7018 10:20... LAS Fife 566 KB PERF 12 OCT 2018 1',r KALOTSA_4 PERF_12OCT18 11/13/201610:05 ... PDF Document 865 KB KALOTSA 4_PERF_120CT13_Correlation 11/13/201810:05 ... LAS File 73 KB KALOTSA 4_PERF 12OCT18_img 11/13,"201810:05... TIFF File 1,171 KB KALOTSA4_PERF_12OCT18_Shooting 11/13/201810:05 ... LAS File 59 KB Please include current contact information if different from above. 80ANNED MAR 18 2819 21 706; 30 50 6 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 • STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 6 2018 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LI Plug Perforations Li Fracture Stimulate U Pull Tubing LI a s i. 6wn Li Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Coil Fishing Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 217-063 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-133-20665-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: (SHL)C061505(TPH/BHL)ADL384372 Kalotsa 4 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Ninilchikk-Beluga/Tyonek Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,221 feet Plugs measured 9,054 feet true vertical 7,958 feet Junk measured 9,061 (fish) feet Effective Depth measured 9,049 feet Packer measured 1,298 feet true vertical 7,789 feet true vertical 1,242 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 16' 16" 120' 120' Surface 1,491' 7-5/8" 1,491' 1,387' 6,890psi 4,790psi Intermediate Production 9,213' 4-1/2" 9,213' 7,950' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic a True Vertical depth See Attached Schematic SeON E° Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Baker Swell Pkr 1,298'MD 1,242'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 499 0 0 822 Subsequent to operation: 0 625 0 155 57 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑✓ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-253 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerehilcorp.com Authorized Signature: e ��a� Date: Z1Z61l8 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 ell 2 -2J-/eR� '!1?°� 0Fi: . ?f18 Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 07/08/2017-Saturday PTW and JSA. Spot equipment and MU 3-1/2"Junk Basket. RIH w/3-1/2"JB and tag at 9,068' KB. The tag was not correlated. SLB didn't have the gama ray to run with JB. POOH. No problems. MU and RIH with CBL, correlate to OHL and tag at 9,075'. Logged to 35'. Swing over to Kalotsa #3 to run CBL. Send log to town. 07/22/2017 -Saturday Obtain PTW. Hold safety meeting. Discuss job procedure with crew. Fire equipment. Pick inj head. stab 10' lubricator. Make up reverse out BHA 2.125" OD 5.6' long. Stab on well. PT BOPE stack to 250/4,000 for 5 minutes each. Open master swab 23.5 turns. RIH. Cooling down N2. PT N2 lines 250/4,000 psi. 1,600' CTMD online with N2 600 scf/min. Increase N2 rate to 150 0 scf/min. Fluid at surface at 6,500' CTMD. Tag PBTD @ 9,093' CTMD. 9,100' corrected KB depth. Fluid return rate increasing at surface. 3,238 WHP/surface N2 pressure. Well blown dry. Continue pumping for 20 more minutes to dry up tubing walls. 139 bbls returned from production tubing. Close choke POOH to surface. Pump N2 AT 800 SCF/MIN. At surface. Close master and swab 2,708 SITP. Town engineer required 2,600 psi. 100 psi additional added for N2 temp change. Previous day attempted to fill IA and used two tank volumes of fluid from field triplex pump. Pressured up IA 4 times throughout day and bleed down to lubricate and bleed air from IA. IA was not full. Started holding pressure. Started 30 minute test at 13:01 @ 2,665 psi. Mechanical gauge on triplex pump holding without bobbles or change. Electronic Transducer gauge would increase and decrease in pressure. This is common early in the AM when acquisition is started and pressure transducer is calibrated. Throughout the day the outside temperature increases drastically, thus causing the transducer to bobble due to thermal expansion. End pressure 2,632 psi @ 1331. SLB rigging down. Coil equipment moving to KGF. Not able to move Cruz crane until Monday morning when permit office opens. 139 bbsl returned from well bore. 186,000 scf pumped for lift or 1,997 gallons. 63,00 scf pumped to pressure up well to 2,700 psi or 676 gallons. 2,708 psi SITP. 08/08/2017-Tuesday PTW. Hold safety meeting with Crews. Discuss E-line job. Spot in equipment. Rig up Pollard crane. RU E-line. Make up GPT/Gamma/CCL. Stab on well. PT lubricator 250/3,500 psi. Bleed down. Open well. Initial WHP 2,550 psi. RIH. Found fluid level at 9,094' RKB. Tagged PBTD at 9110'. Tied into log SCMT_CBL_8JUL17_FINAL. Send log to town.Jacob Dunston confirmed log on depth. Parked GPT tool at 9,080'. Bleeding down WHP of 2,550 psi to drop bottom hole pressure to 2,365 psi. Shut choke. SITP 1,820 psi. POOH to surface. Logging OOH. Tagged up at surface. Close master and swab. Break down GPT/Gamma/CCL. Make up 20'gun 2.875" HC 6 SPF Connex deep penetrators. RIH. Log interval. Send Kalotsa #4 perf tie in log 8-8-18 to town. Confirmed on depth. CCL to top shot 7'. Drop down and pick up to 9,049'. Shoot 20' guns from 9,056'-9,076'. SITP/WHP prior to shooting 1,803 psi. Fired guns. Start POOH. In one hour while POOH we had a 52 psi increase. Tagged up at surface. Shut in well. SITP 1,855 psi. WHP still climbing. RDMO pollard E-line. Turn well over to production. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number •Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 08/25/2017- Friday Arrive at Susan Dione office. Obtain PTW and discuss job procedure. Mobe to location. Fire up and rig up. Load guns. Top shot to CCL confirmed 7.8'. Stab on well. PT stack 250/3,500 psi. Open swab 23.5 turns. RIH. Initial WHP 2,617 psi SITP. Town confirmed correlation log on depth, parked at 9,048.2' with CCL. Puts top shot 9,056'-9,076'. WHP 2,641. Fire 2-7/8" x 20' guns loaded with 6 SPF with GEO connex charges. POOH to surface. No notice in change of WHP gauge. Tagged up. Close swab. Bleed down pop off well. Guns dry. Bull noze on bottom of spent gun only dry perf debris. Rig down and move to Kalotsa #3. Re-open 4 and push fluid away to K-3. Final taken WHP 2,632 psi and still climbing. 08/31/2017 -Thursday Mobe to location. PTW and JSA. Spot and rig up lubricator. PT lubricator to 250 psi low and 3,500 psi high. RIH w/2- 7/8" x 8' HC Connex, 6 spf, 60 deg phase perf gun, tie into HLB Perf log dated 25 Aug 2017 and tag at 9,094'. Run correlation log and send to town, log was 2' low. Directed to perf from 9,037' to 9,045'. Spotted gun and fired with well flowing 642K at 756 psi. After 5 min well flow 652K at 756 psi. POOH. All shots fired. Gun was wet. Well Flowing 618K at 756 psi. Fired gun at 1112 hrs. RIH w/2-7/8" x 8' HC Connex, 6 spf, 60 deg phase perf gun, tie into first correlation log. Spot gun from 9,037' to 9,045' and re-perf zone with well flowing 630K at 756 psi. After 5 min well flowing from 630K up to 648K and in-between at 756 psi. POOH. All shots fired and gun wet. Fired gun at 1340 hrs. Rig down lubricator and move over to Kalotsa 3. 09/11/2017 - Monday Mobe to location. PTW and JSA. Rig up lubricator, PT to 250 psi low and 4,500 psi high. RIH w/2-7/8" x 8' Razor HC, 6 spf, 60 deg phase and tie into perf log.Tag at 9,095'. Ran correlation log and send to town. Was off 3' so was told to perf from 9,072' to 9,080' (proposed zone was 9,075' to 9,083'). Spotted gun with well flowing 582K at 762 psi. Fired gun and after 5 min no change in flow or pressure. POOH. All shots fired. Gun was dry. RIH w/ 2-7/8" x 13' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9,042' to 9,055'. Spotted gun with well flowing 579K at 762.9 psi. Fired gun and after 5 min flow was 713K at 764.1 psi. POOH. All shots fired and gun was dry. RIH w/2-7/8" x 14' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9,021' to 9,035'. Spotted gun with well flowing 823.7 mcf at 767 psi. Fired gun and after 5 min flow was 845K at 767 psi. POOH. All shots fired. Gun was wet. Rig down lubricator and turn well back to field. 11/17/2017- Friday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 4,500 psi high.TP- 1,750 psi. RIH with Weatherford 3.78" OD WRP and tie into OHL. Run correlation log and send to town. Came back 3' low. Adjusted log up 3'. Spotted and set WRP at 8995' with 1,875 psi on tubing. Lost 200 lbs when plug set of line tension. Pick up and sat back down on plug. Good set. POOH. Looks good. Wait on cross over from spangs to catcher sub. RIH w/slickline catcher sub (3.80" OD) and shear catcher sub off on top of plug at 8995'. POOH. Looks good. 1,495 psi. Tools slowed down at 7,250' like it hit fluid or the angle of the well. Rig down lubricator and turn well over to field to blow tubing down to 0 psi.TP- 1,494.8 psi Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 11/20/2017- Monday SLB crews on location. Waited on overload permit to mobe coil unit. Obtain PTW. Hold safety meeting and discuss rig up and BOPE test procedure. RU CTU 13 with 1.75" CT, N2 pump, Choke, return tank. 24 hr bope test witness notification sent 11-19-17 @ 19:04 hrs. Witness waived by Jim Regg 11-20-17 @ 08:33 hrs. Start BOPE test. Accumulator draw down test completed. Test all rams and valves to 250 low and 4000 psi high as per approved sundry. BOPE test complete. Finish rigging up CTU injector. Make up coil connector. Pull test 25K. Location condition report performed with CT supervisor and Co. Rep. Location secure. Crews off location. Return following morning 0700 hrs. 11/21/2017-Tuesday Arrive on location with crews. Obtain PTW. Hold safety meeting. Review JSA and job procedure. Pick injector head. Stab 10' lubricator. Make up roll on coil connector. Pull test 15k. Make up 2 x 1.75" OD x 4' stinger. 1.75"OD x 6" ball drop nozzle. BHA 6'. Stab on well. PT stack 250/4000 psi. Open master swab 23.5 turns. Rig up heater to N2 power unit. Not starting with cold weather. Correct to RKB. Input coil depth to 3.7' . RIH. Air Liquid N2 load ticket 561,327 SCF delivered or 6028 gallons. N2 unit running.Transfer N2. Cool down N2 pump. PT N2 lines 250/4000 psi. @ 5430' CTMD online with N2 1000 scf/min down back side of CT. WHP 77 psi, N2 80*F. Slow down to 10'/min at 8900' CTMD. 835 psi WHP, 734 psi Circ Pressure. Lightly tag Top of plug with 500 lbs down. @ 8992.4' CTMD. No fluid returns seen at surface. N2 returns stopped. WHP steadily climbing. Previous report from slick line fluid level indicated 2200' of fluid column in welbore or 36 bbls. WHP climbing and no returns. WHP 1800 psi. Back down rate to 800 scf/min. WHP 2000 psi. WHP well over what a hydro-static column of fluid at 2200' would be. Drop rate to 500 scf/min. Start POOH from 8992.4'. WHP 2400 psi. No returns at surface. Shut down N2 pump. Continue POOH @ 120 ft/min. Looks like CT is plugged off. Picked up to 5800' plug cut loose. Started seeing Increase in circ pressure. Online N2 600 scf/min. Fluid returns at surface. Returns are pitch black and thick. Looks like sand. Start creeping in hole from 5800'. Returns cleaning up. Increase RIH speed to 65 ft/min. Continue IH. Park CT at 8990'. Increase rate to 800 scf/min. 162,000 scf pumped or 1739 gallons. WHP 1313 psi, circ 79 psi. Slugging Nitrogen then fluid. WHP increasing again 1900 psi. Returns stopped. Looks like CT is plugged again. Start POOH 135 ft/min from 8990'. PU to 7800' WHP dropping Clrc pressure increasing to 85 psi. N2 returns at surface. RIH. Park at 8990' pump N2 bottoms up. Difficult to strap return tank due to amount of snow inside tank from arrival at Kalotsa pad. Cruz Vac truck pulled load and estimated 36 bbls of fluid. POOH. Close choke and increase rate to 1200 scf/min. 193,000 scf pumped before shutting in well and POOH. (2,072 gals).Tagged up at surface. 2568 SITP. Looking for 2400 SITP after N2 becomes static. Master swab closed. Bleed down N2 from reel.Total fluid recovered: estimated 36 bbls.Total N2 pumped 275,000 scf or(2953 gallons.) 193,000 pumped for N2 lift (2072 gallons). 82,000 scf pumped to pressure up wellbore to 2568 psi. (880 gallons). Start rigging down from Kalotsa#4. Move CTU equipment, Cruz crane to Kalotsa #1. Spot up. Install BOP's on Tree. SDFN. Location secure. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 11/22/2017 -Wednesday PTW and JSA. SIMOPS with SLB Coil. Spot equipment and rig up lubricator. PT to 250 psi low and 4500 psi high. TP - 2333 psi. RIH w/2-7/8"x19' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 8843' to 8862'. Spotted gun with 2341.8 psi. Fired gun and TP went to 2342 psi. After 5 min - 2343.3 psi, 10 min -2343.8 psi and 10 min - 2344.5 psi. POOH. All shots fired. Gun was dry. Rig down lubricator and turn well back over to field. 12/14/2017 -Thursday PTW and JSA. Rig up Iubricator.PT to 250 psi low and 4,500 psi high.TP-780 psi. RIH w/3-3/8" x 19' CONNEX HC (loaded w/3-1/8" charges), 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Came back 5' off and was told to perf from 8,848' to 8,867' (8,843'to 8,862' OHL). Had some 100 to 200 lbs over pull while making correlation runs from 8,880' to 8,805'. Called town and discussed. Spotted and fired gun with 963.8 psi on well. Pulled tools up hole 27' and tools became stuck. Worked tools from 2,400 lbs to 3,000 lbs numerous times. Called town and discussed. Flowed well for 30 min. Started from 3,000 lbs tool wt adding 100 lbs every couple times up to 4,600 lbs. Finally acted like tools pulled out of rope socket. Pulled up to 8,550' and started gaining wt. Worked line from 1,600 lbs to 2,500 lbs until 7,500' and came free. Pulled out of hole slow and ended up with a minus 32' in lubricator.Just guessing that would leave from 0 to about 30' of wire plus tool string. I have slickline set up to be out here in the am to fish tools. As far as the perf pressure was 963.8 psi when I shot, 5 min-983.5 psi and 12 min - 998 psi. Rig down lubricator and secure well.TP - 1,215.5 psi. 12/15/2017 - Friday Arrive @ PWL shop, gather fish tools and crew. Depart for Swanson to gather.160" fishing unit. Arrive @ Susan Dionne, sign-in and talk w/co man and permit/JSA. Depart for location, spot equipment, RU .160" wire and 4.5" lubricator. PT lubricator to 3,500 psi, change 0-ring, pass. RIH w/3.7" impression block to 7,980 KB, set down, wt, POOH, picture of clean rope. Socket. RIH w/1.25"JD (w/2.25" bell guide) on 2.80" centralizer to 7,980 KB, latch fish, pull up 1,500-2,000#, tools move up hole 100ft, weight jumping up and down the whole way. Pull up steady to 2,900#, tools come free, cont to pull up with 300#weight loss. Broke wire, POOH, lay down lub. OOH, RU 1.5" .160" toolstring and latch on to slickline tools.Try to shear off E-line tools by beating down but had about 1' movement and could not shear off this set. Also was pinned with a steel pin.This pulling tool was shear up pinned with brass. Sheared tools off and POOH. Will come back in the am with 1-3/4" weights and shear off the tools left in hole and fish E-line tools out. Rig down lubricator and secure well.TP—1,393 psi. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 bail '0 erations: Y� p 12/16/2017-Saturday Arrive @ Susan Dionne, sign-in/permit/JSA/talk about days operations and plan. Forward focusing on slips-trips-falls due to icy conditions and a brief discussion. About pinch points. RU slickline, PT lub to 3,500 psi. TP-1,465 psi. RIH w/2.5"jus w/3.53" bell guide to 7,834 KB, latch slickline fish, POOH. OOH w/fish, redress tool. RIH w/ 1-1/4"JD to 7,855 KB, latch e-line fish, give 4 oil jar licks up to 2,200#, tool slips. Off, POOH w/two broken dogs on pulling tool. RIH w/overshot baited w/g-fish neck to 7,835 KB, set down high, wt, cannot pass. POOH with overshot left in hole, possible wire in hole or tight spot. RIH w/3" GS on 3.23" centralizer to 7,835 KB, latch overshot,give three 2,000#jar. Licks and comes free, POOH w/overshot, marks on opposing sides. RIH w/3-prong wire grab baited w/2.5"JUC to 7,835 KB, set down and wt to 7,855 KB. Pick up and have 200#extra pickup weight, work tool through 7,835-7,855 KB, POOH. OOH w/wire across valves, pinch wire with master valve and set down with tools to ball up more wire and pull rest of wire through valves, well is shut and bleed down lubricator, recover"'20ft of.160" wire. RIH w/3.7" impression block to 7,855 KB, POOH. RIH w/overshot baited w/G-fish neck to 7,855 KB, latch e-line tools, pull two 1500#. Jar licks and one 2,000#jar lick, come free and chase tools up hole, lost tools. Again. OOH, RD slickline, prep for.125" wire for previous morning. Depart field.TP-1,465.9 psi. 12/17/2017-Sunday Arrive @ Susan Dionne, sign-in, permit/JSA, talk about plan forward -well had 150 psi increase from previous day since the time of breaking wire - blown up hole. Arrive on location, start and warm equipment, RU .125" wire. RIH w/3.5" impression block to 7,680 KB, pick up and appear to be dragging wire, POOH PT-1,605.8 psi w/impression of 2" tail of wire and top of rope socket. RIH w/3.75" blind box to 7,688 KB, hit down 20X, POOH pulling 1,100# up to 7,485 KB and then weight dropped to 700#, cont POOH. PT-1,594 psi. RIH w/baited 3-prong wire grab on 2.5"JUC to 7,668,KB, wt up and down and pull up.To 7,663 KB with 1,100# bind,jars go off and POOH with 300 extra #, POOH. PT -1,600 psi. OOH w/slickline fish, pause the job to discuss hazards of toolstring hanging off of wire grab and possibly giving way and falling, and other scenarios, break. Down fished toolstring and check pin in JUC. RIH w/same to 7,690 KB,get 120#overpull, set down couple times, POOH. OOH w/"20ft ball of wire, PT-1,590 psi. RIH w/3.5" impression block to 7,711 KB,tag top of G-fish neck on overshot, POOH w/impression of strand of wire bent over top of G-neck. PT-1,578 psi. RIH w/2.95" 3-prong grab baited on 2.5"JUC to 7,713 KB,get 200#overpull come free. PT-1,575 psi. No extra weight, set back down and pick up again, no extra weight, POOH, no wire. RIH w/3.75" blind box to 7,710 KB, wt, POOH while pressuring up on well to 1,850 psi and pressure was still building (ran line from #2 to#4). RIH w/3.5" lib to 7,710 KB, hit down once, POOH w/picture of clean G-neck. Lay down for nite to let well continue to build downhole pressure- PT 1,847 psi and building. 01/04/201 'y-Thursday Check in at Suasan D. Obtain PTW. Hold safety meeting and discuss job procedure and pressure test procedure. Fire equipment. Spot in and rig up. 24 hr. BOPE test witness notification sent to state on 1-2-18 @ 14:34 hrs. Witness waived by Jim Regg on 1-2-18 @ 14:36 hrs. Start BOPE test. Pressure test all rams and valves to 250/4,000 psi. BOPE test complete. Clean up Location. Secure wellsite. SITP 1,750 psi. 4111 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/05/2017- Friday PTW. Hold safety meeting with crews and production operator. Pick injector and install 40' lubricator. Make up Weatherford fishing tools on 1.75" CT. External CC 2.37" OD x .86', DFCV 2.19" OD x 1.17', Dailey BI/DI oil jars 2.25" OD x 7.53', 5/8 ball disconnect 2.19" OD x 2.04', 3" Hyd GS spear 2.5" OD x 1.4', (2.31" ID catch).Total BHA length is 13.02'. Stab on well. Pt stack 250/4,000 psi. Open well. Initial WHP 1,747 psi. Coil corrected to RKB. RIH. Pipe displacement caused WHP to climb to 2,030 psi. Bleed back to 1,750 psi. Perform weight check prior to latching into fish. 13,700 lbs at 7,519'. RIH. 7,990' CTMD stacked to -9K. PU and over pull to 23,331 lbs and moved fish 7,611' and weight over pulled to 35K. Work tool string. Dragging fish OOH weight gauge bobbled all over. Tagged up at surface, master swab closed 23.5 turns, pop off well. Fish recovered. Wire hanging out of lubricator and into BOP. Attempt to pull out by hand. Stuck across valves. Pull E-line free from lubricator. Break down guns and fishing tools. All shots fired on HSC 20' Gun 3 3/8" OD. Break down lubricator. Set injector head on back deck. Called town to discuss. Called out Pollard SL at 1500. Wait for Pollard SL to arrive. SLB secure equipment and depart location. Pollard SL on location. Rig up SL. Attached wire in BOP and stab on well. Equalize. Open swab and master 23 turns pulled up 36'. Close master. Pop off well. Recovered 6' of E-line wire. Install wire grab on SL. Stab on well. RIH and tagged below master valve. Over pull. Feels like wire attached. POOH. Close master. Pop off well. 8"of E-line wire and estimated 4' of slick line wire recovered. Stab back on well. Open master, 0-ring leaking. Close master and bleed down stack, pop off and change out lubricator 0-ring. Stab back on well. Open master. RIH with wire grab. RIH to 7,425' and stack weight. POOH. At surface. recovered 3' of E-line. Removed E-line. Stabbed back on well. RIH w/LIB. Tagged at 7,425' and lost weight, tried to catch weight. POOH and no tools are on wire. Counter shows 245' of wire left in hole. 01/07/2017-Sunday Arrive at Susan D.Touch base with pad op. Schlumberger pump operator and Pollard slick line obtain PTW. Hold safety meeting and discuss plan forward. RU Pollard SL unit with .160" wire. Stab on well. Fill SLB displacement tank with methanol. Finish making trips with truck day tank and field triplex to Susan D to Kalotsa Pad. 15 bbls loaded. PT lubricator 250/3,000 psi. Bleed down to well. Pump 16.1 bbls of methanol down the hole to aid in hydrostatic pressure. 1,456' of additional fluid level added. RIH w/4" GR w/ baited 3.95" wire finder wire spear to 7,159'. Pull heavy. Seemed as if wire was slipping off. Attempt to latch multiple times with no luck. POOH. Found fluid level to be at 5,800'. Puts fluid level prior to adding the methanol at 6,850'. Close master swab. Pop off. Noticed some marks on wire spear. RIH with 3.75" LIB to 7,159'. POOH. Tagged up. Close well. Pop off perfect indention of rope socket with no wire noticed on LIB. • • Hilcorp Alaska, LLC Summary Operationsy Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/09/2018-Tuesday Fill out PTW. Hold safety meeting with SLB, Cruz,Weatherford, Hilcorp pad operator and HAK safety rep. Start equipment. Pick injector head. Stab 40' of 7" lubricator. Coil connector still installed from previous run. Pull test CC 25K. Make up DFCV, Hailey BiDi jars, Hyd disco, Hyd release JDC overshot. Tool length 13'. Stab on well. PT stack 250/4,000 psi. Open master swab 23 turns. RIH. Initial WHP 893 psi. Wellhead pressure climbing as CT displacement increases. 6,000' WT check 7,100 lbs. 7,000'WT check 8,700 lbs. 1,103 psi WHP. Stack 7K down @ 7,160'. PU to 25K 7,144' 16,300 lbs over pull. Wait for jars. Jars fired. No movement pull to max 80%coil limit 40K. No movement. Perform 5 jars likes up from 7,137' . 31,300 lbs over string weight. No movement. Attempt 10 down jar licks only. Stack-15K down at 7,156'. No movement. Continue with max up jars at 40,000 lbs. 50 up jar lick limit. Pump 40 bbls of produced water and pump off fish profile with hydraulic release JDC overshot. POOH to surface. Cool down N2. Close master and swab. Blow reel dry. Pop off well. Break down BHA. Stack down 40' of lubricator.Trim 150' of coiled tubing. Pipe maintenance. Well site secure. Crews off location. 01/10/2017-Wednesday PTW. Safety meeting with SLB, Cruz crane operator, Weatherford tool hand, and production operators. Production shoot fluid level. Came back 4,760 on echo meter. PU injector head. Stab 55' of lubricator(previous fishing tools were 2-1/8"jars only). RU new fishing tools, external CC, DFCV, 3-1/8" Up jars, 2x 10' weight bars 22 lbs/ft. Hydraulic disconnect, 3.5" Hydraulic release JDC overshot with 1.75" catch. Stab on well. Pt 250 low and 4,000 psi high. Open master swab 23 turns. 160 psi initial WHP. RIH wt at 7,000' 2K. WT chk 7,000' 11K. Stack-4K @ 7,163' CTMD. WHP increased to 365 psi while RIH. Pick up to 40K or 29,000 lbs over string weight at 7,143'. 12' of stretch on CT. Jars fired after 20-30 seconds. RIH to reset jars. Attempt different over pull weights to see where jars would fire the best. 40K looked desirable. Continue resetting jars and pulling to 40k to jar. After 20 jar licks start RIH stacking max of-20K. 35 licks shut down for 30min to cool jars. Let jars cool down with -18K stacked down on fish at 7,157'. Back to jarring on fish. No movement yet. Jar#46 pu to 7,149.9' and 41K up wt. Jars fired. Coil started moving OOH at 12,700-13,000 lbs. Roughly 2K over pull from or free string weight of 11K. Pick up 200'. RIH. Stack-8K down at 7,157' CTMD. PU 14K 3K over and weight broke back to 12,500 lbs. Still slightly heavy. Possibly have fish or brokew/ore out overshot dogs. POOH to surface. Tagged up SITP 125 psi. Close lower master. Pop off well. Fish on. Half the fish removed. Looks like sucker rod threads between knuckle joint and oil jars backed out until a few threads remained and then stripped remaining threads. Fish removed from well 6" rope socket, 2.25"x 5' stem, 2.25"x 3' stem, 1.75" x 8" knuckle joint. Total length of fish recovered. 9'2". Remaining fish in hole 245' (estimated) .160" SL wire. 1.75" x 3' Oil jars, 1.75" x 5' spangs, 3.75" x 8" LIB (1.75" fish neck). Total fish tool length remaining in hole 8' 8" and 245' of.160" wire. Break down Weatherford tools. Cut 150' of coil. Stack down lubricator. Set inj on back decK. CTU rigged bacK. Cruz crane moved to edge of pad. Production shoot fluid level. Echo meter reads 4,592' with 125 psi SITP. Location secure. SDFN. Plan forward will be to RIH with slickline and LIB. If wire is shown, attempt to fish wire. If good impression of sucker rod rig down SL. Move in coil the following day. New jars coming from Anchorage. 3-1/8" bi directional jars vs up jars only. . • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/11/2017-Thursday PTW. Safety Meeting. Discuss job procedure. Rig up .160". P/T LUB WLV 2500 psi. RIHw/4-1/2" Wirefinder w/stem 3' Long w/3.75" LIB to 1,150' fall slow to 4,000'fall fast,tag fluid at 4,850' continue to 7,176' KB w/t 3 hits. POOH. OOHw/impression of wire marks. RIH w/2-1/2" RB w/ bait sub w/3.75" centralizer w/ wirefinder w/center spear 3' long (overall 79")to 7,175' KB (RB depth BTM of spear was 7,182' KB) w/t down to 7,179' KB (spear btm at 7,186' KB) then start w/t with jar licks, shear off baited spear and POOH. RIH w/2-1/2"JDC (heavy skirt w/4 dogs)to 7,175' KB w/t latch w/t come free with weight and a small amount of overpull,continue POOH to surface. OOH w/ 15' wire. RIH w/2-1/2" RB w/bait sub w/3.75" centralizer w/wirefinder w/3 prong 2.73" wire grab (overall 61")to 7,177' KB w/t get good overpull couple hundred lbs pickup 10' then go tight get 600 overpull w/t shear and POOH. RIH w/2-1/2"JDC heavy skirt to 7,181' KB wit, 2x 1,400 lb jar lick, come free, POOH, OOH w/5' of wire. RIH w/2-1/2" RB w/ bait sub w/ 3.75" centralizer w/wirefinder w/3' long center spear(79")to 7,180' KB (btm of spear at 7,187' KB) w/t to 7,182' KB (spear 7,189' KB) w/t multiple jar licks. Appear to shear POOH. OOH w/baited spear no wire. RIH w/2-1/2" RB w/bait sub w/3.75" centralizer/wirefinder w/ 1 and half prongs wire grab (59" overall) to 7,183' KB w/t set bait sub w/t shear and POOH. RIH w/2-1/2"JDC heavy skirt to 7,183' KB (btm of grab 7,188' KB) w/t latch w/t pull up to 7,172' KB 500 overpull appears to be pulling line tight down hole w/t one jar lick come free. POOH. OOH w/no wire but the short prong on grab is bent in. RIH w/3.75" LIB to 7,185' KB, w/t POOH, OOH w/imp of wire (this is 3' higher then grab got) talk to Cole. RIH w/4" GR w/int bait sub w/ KJ w/2 prong grab 1 Prong 3' long other 1' to 7,185' KB (btm of grab 7,189' KB). Multiple jar licks to come free. POOH. OOH w/baited grab still on string. RIH w/4" GR w/int bait sub w/ KJ w/ KJ w/4 prong grab 1 long prong (62" overall )to 7,183' KB (btm of prong 7,188' KB) w/t to 7,185' KB (btm of prong at 7,190' KB)then w/t up to shear. POOH. RIH w/4" GS to 7,185' KB w/t latch w/t 33 jar licks 3,000lbs to 3,500Ibs, beat to 7,181' KB come free POOH. OOH w/bait sub to grab, no wire, grab was damaged, lay down slickline, clean and secure area. Send out reports.Turn in permits at Susan Dionne. Last run appeared to have beat wire to the point that it probaly got straightened and pulled free.Total wire fished 19'. Not able to get a good LIB impression of the fish neck. LIB stacks higher than when we run a spear. We will continue with SL operations at 0700 hrs. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/12/2017- Friday Arrive at Susan D. Fill out PTW. Hold safety meeting with crew. Fire SL unit. Pick up lubricator. Cut wire/re-head. Initial WHP 1,460 psi. Jump pressure from Kalotsa 2 to Kalotsa 4. Pressure increased to 1,750 psi. Make up wire grab. RIH. Crew noticed wire going through top chive was touching crane wire rope. POOH to surface. Wire was twisted around main line. RIH, tagged at 7,187'. Beat down. Shear up and leave baited sub in hole. POOH to surface. RIH with 4" GS pinned to shear down. 2,600-3,000'jar licks. 5 jar hits. POOH. Recovered 5' 3" of wire. Wire was pushed up 8" into wire grab. Indicating that we made it over oil jars left in hole 3". RIH with 2.49" LIB centralized. Tag @ 7,187'. Spang down. POOH. At surface. Good impression of fish profile. 3/4" rod from parted oil jar piston. Make up series 70 baited overshot dressed with 1.75" catch. Baited with 3" GS internal fish neck. Total length 4.958". RIH with series 70 overshot, dressed with 1.75" catch. Fluid level 4,770'. Tagged at 7,187'. Spang/jar down. Made 1" to 7,188'. Good indication of overshot latch (overshot has 13" barrel. POOH to surface. Rig down Pollard SL. Well site secure. 01/13/2017 Saturday PTW. Hold safety meeting. Discuss BOPE test procedure, fire equipment, 24 BOPE test witness notification sent to state on 1/12/18 @ 16:09. Witness waived by Jim Regg 1/13/18 @ 10:41. Start BOPE test. Test all rams and valves to 250/4,000 psi. 4.06" Combi BOPE stack (2 rams). Wind picking up during BOPE test. Take multiple wind readings from manlift, consistent wind of 25-28 MPH. Gusts of 31-35 MPH. SLB and Cruz Crane limit 30 MPH. BOPE test completed. Shut down job due to high winds. Secure location. 01/14/2017-Sunday Fill out PTW. Hold safety meeting. Discuss job procedure with crews. Fire equipment. Pick injector head. Stab 50' of lubricator. Make up BHA. Pull test CT connector to 25K. Fish BHA details. 2.875" x 2.48' MHA with CC/DISCO, 3.125"x .84'XO sub, 3.125" x 11.39' Fishing slinger, 3.125" x 9.45' wt bar(22 lbs/ft), 3.125" x 7.9' Bi/Di jars, 3.125" x .66" xo sub, 2.875" x .46"'xo sub, 2.5" x 1.4' 3" HYD GS spear. BHA total length 34.58'. Stab on well. PT stack 250/4,000 psi. Good test. Bleed down. Open master swab 23 turns. 1,550 Initial WHP. RIH. Continue RIH. Perform weight check prior to latching fish at 7,000' CTMD. PU WT 9K. 1700 psi WHP. RIH to latch fish. -4K RIH wt. Stack-6K @ 7,164' push to-14K.Took 5 attempts to get a positive latch into GS spear. Possible chunk of wire between fishing profiles. Start jarring process. 10 down licks no movement. Continue jarring in both directions. Up Jar#52 pulled to 39K @ 7,147.5' Jars fired, fish moving. Fish still dragging pulling heavy at 20K but weigh broke over and coil pulled out of hole to 7,136.6' and tripped out at depth 41K. Monitor coil life. Attempt a few more jar licks. No luck. Coil cycled out. Pressure up on CT with -10K stacked down. Pressure up on coil to 3,500 psi. Pick up and release from GS fish profile baited to series 70 overshot. Fish still remains in hole. 1.75" oil jars, 1.75" spangs,X over and 3.7" LIB. Baited with 3" GS, x over, 3.5" OD series 70 over shot dressed with 1.75"grapple. POOH to surface. Blow down N2 reel and freeze protect with 3 bbls of methanol. N2 bleed down. Pop off well. Break down Weatherford fishing string. Stack back lubricator and injector head. Trim 150' of pipe to move fatigued coil deeper in hole from cycling pipe across gooseneck. 0 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/15/2018 - Monday PTW. Hold safety meeting. Discuss job procedure. Review SLB JSA. Pick injector head. Make up 50' of lubricator. Make up External CC. Pull test to 30K. BHA details. 2.875" x 2.48' MHA. 3.125" x .84' xo, 3.125" x 11.39' Slinger, 3.125" x9.45' WT bar, 3.125" x 7.9' dual acting jars, 3.125" x .66' xo sub, 2,875" x .46' xo sub, 2.5" x 1.4' 3"HYD GS spear. BHA length 34.58'. Sab on well. PT stack 250/4,000 psi. Open master swab. RIH. Initial WHP 0 psi. Weight check at 7,000' 9K. RIH wt 1,700 lbs. Previous day latched fish at 7,164'. Started stacking weight at 7,157'. Stacked to 7,155' and -15K. PU to 40K 7,138'. Paint blue flag at gooseneck. Stack back down to 7,155'jar down. PU to 7,138' and jar up. Repeat 3 times. On 4th attempt pulled out of GS profile. Attempt to re-latch fish. PU to 7,138' @ 40K. Up jar lick. RIH, stack weight, PU and pulled free from fish. Pulling 2K heavy with weight bobbles. It is not normal to pull out of GS spear so easily. Decided to POOH to surface. At surface. Close well. Pop off and inspect GS spear. Able to pick up and retract piston sleeve with one hand. Normally it needs 2x 24" pipe wrenches to retract piston sleeve. Break off GS. Take GS apart in tool shed. Clean and reassemble. GS spear is functioning as normal. Install 3" GS spear on fishing tool string. Stab on well. PT stack 250/4,000 psi. Open well RIH. 7,000' wt 9K. Stack weight at 7,139.5' @-14K down. PU. Latched in, start jar sequence. 3rd up jar noticed WHP increase from 0 psi to 150 psi then back to 0 psi. Each up jar to 40K at 7,139'. Down jars at 7,157'. 70 up jars licks and 50 down jar licks. Pump methanol followed by N2. Pumped off GS spear. POOH to surface. POOH. Close master swab. Pop off. Primed up with N2. Ensure coil is blown down to open top tank for freeze protect. Break down tools. stack down lubricator. Remove BOPE stack. Coil unit rigged down. Remaining support equipment left on location. Coil crews will de mobe CTU unit in the am. Swap injector blocks, pack offs, BOP inserts and reel. We will return to fish with 2.375" CTU. 01/18/2017 -Thursday SLB arrive on location. PTW. Hold safety meeting. Discuss BOPE test procedure. Move in 2.375" CTU. MU remaining 1502 iron. 24 hr BOPE test witness notification sent 1/17/18 @ 12:08 PM. Witness waived by Jim Regg on 1/17/18 @ 12:10 pm. Start BOPE test. Test all rams and valves to 250/4,000 psi for 5 minutes. BOPE test complete. Fluid pack 2.375" CTU with Lease water. Pump 60 bbls. Rust indicated at return tank. Pump 1 bbl neet methanol. Online with N2 to blow reel dry. N2 at return tank. Manifest cruz vac truck for G&I. Pop off well with injector head. Install BOPE night cap. Secure well site. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/19/2017- Friday Obtain PTW. Hold safety meeting. Discuss job procedure. Stop work authority and obligation. Pick injector head and make up 50' of lubricator. Re-pull test coil connector to 40K. Make up Weatherford fishing assembly: 2-7/8" OD dimple connector x .59', Hydraulic disconnect (7/8" ball) 2.875" OD x 1.79', x over 3.125" OD x .84', Weatherford slinger 3.125"OD x 11.39', weight bar 22 lbs/ft, 3.125" OD x 9.4', dual acting jars 3.125" OD x 7.9', XO 3.125"OD x .66', XO 2.875"ODx .46', 3" Hyd GS spear 2.5" OD Stab on well. PT lubricator 250/3,180 psi. Good test. Open well RIH. 368 psi WHP. 7,000' wt Check is 15K clean up weight. RIH to tag fish. Tagged fish at 7,128' CTMD (previous tag depth with 1.75" CT 7,159' CTMD) 31' difference. Possible pipe stretch or we slightly moved fish. OOH. Start jarring. Looking for jars to hit at 54-60K on weight gauge. Max over pull 45K on jars would be 60K on weight indicator with 2.375" CT. Picking up as fast as possible jars firing at 30-45K on weight gauge. PU to 60K. 7,115.4' paint flag. Continue with up down jar licks. PU on jar lick 38 to 7,042'jar fired and pulled over to 65K. Pulling OOH 5-10K heavy. Pick up to 7,000', still 5k heavy. RIH to check for tag. Stack at 7130' -15K. PU still have over pull. POOH to surface and check tool string. Tagged up upper master and swab 23.5 turns. Popped off. RIH. Baited fishing assembly and series 70 overshot recovered. Looks like we pulled jars apart. 4" of jars body remain. Jar balanced piston floating around in hole as well. Small non-magnetic piece. 2.25" overall length with 1.31" OD to 1.02" OD. Pictures taken later at Pollard shop and sent to town. Fish remaining in hole. 4" of oil jars 1.75" OD. 5' of 1.75" OD spangs. 3.7" LIB x 8". Fish schematic sent to town. Travel to Pollard SL shop with fish. Send details to town. Wellsite secure. 01/20/2017 -Saturday On location -JSA- permit—TGSM. Rig up WL- pick up 4-1/2" WLV's and lub- PT lub w/well bore -good. RIH w/3.95" wirefinder w/3.5" LIB to 7,177' KB wt- POOH -OOH w/wire marks on outside. Edge of LIB and unidentified mark w/ metal shavings on center. RIH w/3" GR w/ bait sub w/ barrel style wire grab to 7179' KB wt-friction bites 600 lbs. Overpull -continue to slip off- POOH -OOH w/ bent prong inside grab. RIH w/3" GR w/ bait sub w/ prong style grab to 7,179'KB wt-cannot grab wire - POOH. RIH w/3.75" LIB to 7178' KB wt- POOH - clear impression of bottom sub of oil jars and faint impression of wire on side. Rig down WL- secure well. Mob to PWL shop. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/22/2018- Monday PTW. Hold safety meeting. Discuss JSA. Pick injector head.Stab 50' of lubricator. Make up Weatherford BHA. CC, MHA,xover, dual acting jars,xo, HD disconnect, CTD fishing motor, 2xovers, drive sub, burn shoe extension 3.75" OD x 3.25" ID, x 3', shoe extension with tattle tale pins spaced 6" apart, burn shoe with cut rite bit 3.75" OD x 3.25" IDx 2.66'. Total length 37.34'. RIH. Fill CT. PU weight at 29K at 7,053', pumping 2.5 bbls/min 1,240 psi. RIH wt while pumping 3,782 psi. 7,132' WHP spiked 460 psi. 7,136' PU wt clean, 7,164' stack-5K stall motor. PU establish free spin. Circ pressure increasing each time we pick up after a stall. Continue to attempt to mill/burn over spangs to LIB. 7,163' stack weight. Shut down pump. Attempt down jar lick at-25K CT weight. PU clean. Circ pressure now up to 3,275 psi. Can't get motor to stall fast or spike sharp on circ pressure. POOH to check tool string. POOH.Tagged up. Pop off well. Break down burn shoe. No tatle tales broke. Indicating we did not get over fish. Motor would not spin in any direction with use of 24" pipe wrench. Motor bearing box was possibly locking up during job as to why we kept seeing an increase in circ pressure.Tools off. Stab on well. Blow down reel to return tank. Pop off well. Stack down lubricator. Install night cap on BOPE. Well site secure. Crews off location. 01/24/2017-Wednesday PTW. Hold safety meeting with SLB, CRUZ, Weatherford, HAK production operator. PTW signed. PU injector head. Stab 50' of lubricator. Make up Weatherford fishing assembly with burn shoe. Stab on well. Pt stack 250/3,500 psi. Open well. RIH. No WHP upon opening wellbore. Trip in hole 96 ft/min. 7,150' wt Check with coil fluid packed. 28K up weight. 3K RIH wt. Tagged top of fish at 7,163' CTMD. Pumping at 2.2 bbls/min 1400 free spin pressure. Noticed first motorwork at 7,163.3'.Tagged fish at 7,161.3'. Wore burn shoe to 7,163.52'. Had 15 stalls at same depth. Time to POOH to check burn shoe. POOH to surface. Tagged up. Burn shoe tattle tales broken. We burned over 3.25' or 3.75' of fish. Currently at or within an inch of LIB. 8" of slick line .160" wire removed. Tattle tales were broke inside burn barrel at least 3.25' but fish could have made it close to the next tattle tale at 3.75'. Break down BHA and call town to discuss plan forward. We will run new burn shoe in the AM. Tools broke down. Stab on well. PT N2 lines 250/4,000. Blow CT dry. Pop off well. Cut coil connector. Trim 100' of 2.375" pipe. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 01/25/2017-Thursday Obtain PTW. Hold safety meeting. Review SLB JSA and sign. Fire equipment. Pick injector head . Make up 50' of lubricator. Cut 100' of coil. Make up new dimple connector. Pull test connector to 45K. BHA details: internal dimple connector 2.87" OD x .91', HD MHA 2.88" OD x 1.66', x over 3.38" OD x .89', dual acting Jar 3.12" OD x 6.7', x over 3.13" OD x .89', HD disco 2.88" OD x 2.27', circ sub 2.88" OD x .66', motor 2.88" OD x 10.61', Burn shoe 3.75" OD x 11.41'. Total BHA length 37.57'. Stab on well. Fluid pack. PT stack 250/4,000 psi. Good test. Bleed back to tank. Open master and swab. 23.5 turns. 0 WHP. Start RIH. Fluid pack reel with 42 bbls of KCL. 7100' WT CHK 34K.Tagged top of fish at 7166' CTMD. PU clean 35K. Online 2.5 bbls/min Free spin 1745 psi. RIH to find motor work. Stall motor at depths of,7165.2', 7,164.786', 7,165.52', 7,164.28'. Stalled and pulled heavy to 39K. 4K over string weight. Continue to stall 7,164.4'. Stalls are fast and grabby. Probably wire. Picked up to 7,050'. Close choke. Pressure up wellbore to 3,200 psi. RIH 100' per minute to hit fish. Pressure dropped instantly to 500 psi. RIH and tagged top of fish at 7,204'. Moved SL fish in hole 40'. Pick up clean 35K. Online at 2.6 bbls/min. Slowly stack out on fish at 7,204'. Stall motor. Picked up to 7,000'. Call town to discuss plan forward. POOH to surface. Contact Pollard slick line for tomorrow. Tagged up. Pop off and remove burn shoe barrels. Wire bundled inside. No new tattle tales broke. Still only made it over 3.25' to 3.7' with burn shoe. Straightened and measured wire bundles recovered. 56" recovered on today's run and 12" recovered on previous day's run. 5.6' of wire removed with burn shoe. Pumped 375 bbls of KCL. Stab on well. Blow coil down with N2. Pop off well. Stack down lubricator and set injector on deck. Clean up location. Location secure. 01/27/2017 -Saturday Obtain PTW. Hold safety meeting with Pollard crew and production. RU Pollard slick line unit. MU. RIH w/3.49" LIB on XO on 3.9" wire finder to 7,217' KB w/t POOH wire marks on LIB. RIH w/3 prog wire grab on 3.9" wire finder on 2-1/2" JDC to 7,219' KB w/t 7,220' KB. See 250lb overpull comes free. POOH, see metal marks on grab. RIH w/3.5" mag on 3.9" wire finder to 7,219' KB wt- POOH - OOH w/ metal shavings, no wire. RIH w/3.49" LIB to 7,219' KB wt- POOH - OOH w/ impression of top of fish - no wire. RIH w/2.5"JDC w/ baited 3.9" wire finder w/2 prong grab to get beside fish to 7,219' KB wt, could not latch - POOH -OOH w/wire finder flat on tip. RIH w/over shot 1.75" grab on 3" GR to 7,220 KB wt- latch fish 4 oil jar licks. Shear tool - POOH. RIH w/3" GS to 7,220' KB, hit 40 OJ licks up to 3,8001b, no movement shear off. POOH. Location secure. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 paiIypparapio st '41:1 clitZa, 01/28/2017-Sunday Obtain PTW. Hold safety meeting with SLB, Cruz, HAK production. 24 hr. BOPE test witness notification sent 1/27/18 @ 17:01 hrs. Witness waived by Jim Regg on 1/27/18 @ 18:35 hrs. Start BOPE test. Test combi rams and choke valves to 250/4,000 psi. BOPE test complete. PU injector head while BOPE testing. Stab 50' lubricator. Make up Weatherford fishing assembly. BOPE test complete. Finish making up BHA. Stab on well. PT stack 250/4,000 psi. Open well. 0 whp. RIH. WT check 7,000' CTMD. 19K. RIH WT-4,800 lbs. Tag top of fish 7,200'. PU 50K weight breaking off. Fish slowly moving up hole. Keep pulling. PU @ 7,160'to 50K. No jar lick. Attempt to reset jar. Jars are not firing up. Try down jar lick at 7.160'. Small lick possibly. Discuss jar performance with tool hand,jars are not functioning. Stack to-30K, wait 3 minutes no jars. PU to 70K. Weight break back to 19K original up weight prior to latching fish. PU to 7,000'. RIH to tag at 7,160'. POOH to surface.Tagged up. Pop off well. RIH. Missing bottom fishing assembly. 3" GS spear, x over, and 1/2 hydraulic disconnect with 3" GS internal fishing neck. Stack down lubricator. Weatherford making calls to arrange for fishing tools. Well site secure. Crews off location. 01/29/2018- Monday PTW. Hold safety meeting and discuss job procedure and safety concerns. Fire SL equipment. RU Pollard SL unit. Make up tools, RS, 2x stem, knuckle joint, oil jars, spang jars, 3" GS spear. Stab on well. RIH w/3" GR to 170KB. Latch fish @ 1,300Ibs to 1,500Ibs. See spang on fish open. Beat spang jars open and shut 10 times to try to beat down but won't move. Hit 3 OJ licks up to 2,400lbs. Tool sheared. POOH.At surface. Close master and swab. Rig down Pollard SL. Leave equipment on location. 01/31/2017-Wednesday Obtain PTW. Hold safety meeting. Discuss JSA and review job procedure. Pick injector head. Stab 50' of lubricator. Make up BHA: CC 2.88" x .91', DFCV 2.88" OD x 1.33', x over 3.125" x .83', slinger 3.13" OD x 9.41', weight bar 3.13"OD x 9.53', Daily DAJ 3.13' OD x 7.79', x over 3.13" OD x.87', Disco 2.88" OD x 2.27', x over 3.13" OD x.67', 3" GS spear, 2.13" OD x 1.55'. Stab on well. PT stack to 250/4,000 psi. Bleed down. Open master and swab 23.5 turns. Initial WHP 465 psi. RIH 7,000' wt check with coil dry 19K. RIH WT-3K. Stack 10K down at 7,160' CTMD. PU latched to fish pull to 7,152' @ 40K. Fire jars. Slack off-32K at 7,158' down jar lick. Pick up and break over at 19K. Possibly pulled out of fish profile. Attempt to engage GS fish neck 5 more times. No luck latching. POOH to surface. Continue POOH to surface.Tagged up. Pop off. GS spear in retract mode. Tool full of sand/silt debris. Clean profile. Reinstall. Stab on well. PT stack 250/4,000 psi. RIH. Fluid pack coil. Wt check 7,100' 32K. RIH wt 2,300 lbs. Tag with 10K down at 7,160'. Pressure up well to 3,200 psi. Down jar lick at-30K. Push fish in hole to 7,238'. Work fish in hole to 7,586'. PU good latch and over pull. Pull heavy. Work fish OOH.Jar lick up at 7,160'. POOH to surface. No fish. GS spear looks good. Clean GS spear. Stab on well. PT stack 250/4,000 psi. RIH. 0 psi whp. 7,100 wt check 32K. Tag fish and or push fish and tag at 7,314'. Jar down. Online with pump down CT and backside 6 bbls/min pressure increased to 2,800 psi with -30K stacked. Fish broke free. RIH. 7,492'. Stacked weight. PU and jar down. Continue to work fish in hole. Fish pushed to 9061.6'.Stack-30K. Online 2 bbls/min 3,200 psi, pump off fish. POOH to surface. At surface. GS in retract mode again. Break down tools. Set down lubricator. Stab on well. Blow coil down with N2. Set inj head on deck. Well site secure. Crews off location. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kalotsa 4 E-Line 50-133-20665-00 217-063 7/8/17 2/2/18 Daily Operations: 02/01/2017-Thursday Hold safety meeting. Talk about well work plan and associated hazards. Spot in equipment. 0 psi WHP. RIH w/3.75" LIB TO 9,043' KB set down -wt- POOH -OOH w/ impressoion of coil disconnect. Wait for Pollard E-line. RU Pollard E- line. Gamma ray has ground. Not functioning correctly. Wait on hot shot. RIH with 4.5" CIBP 12' from CIBP to CCL. Tag uncorrected depth at 9,035'. Pull strip and tie into perfs. Talk with town. Plan changed to set CIBP on top of fish instead of 9,010'. Set CIBP at 9,054'. POOH. At surface. Load 3.2 gallons of cement giving us 5'. Stab on wel . RIH, dump cement 9,054'. POOH to surface. Rig down PESI. Well site secure. 02/02/2019'j- Friday PTW. Hold safety meeting. Discuss job procedure. PU injector head. Stab 10' lubricator. Make up 3.125"jet swirl nozzle. Stab on well. PT stack 250/3,500 psi. RIH. Initial WHP 0 psi. CT @ 9,000'. Online down coil at 3 bbls/min. FCO. Pump 295 bbls of KCL. N2 cooled down. PT N2 lines to 250/4,000 psi. Blow well dry with N2 at 1,000 scf/min. CT parked at 9,000' CTMD. Well blowing dry. Drop N2 rate 800 scf/min. Start POOH 45 ft/min. 126 bbls lifted from wellbore. Only N2 at surface. 1.2 PPM H2S reading on Gas meter. At surface. SITP 165 psi. Rig down SLB CTU 13. 125,000 scf pumped. 1,200 gallons remaining. Location secure. - • + Ninilchik Unit , ll SCHEMATIC Kalotsa #4 PTD: 217-063 API: 50-133-20665-00 I lilcarp Alaska,LLC RKB to GL=18' CASING DETAIL 16" - , ► Size Type Wt Grade Conn. ID Top Btm .. Conductor-Driven or 16" to Set Depth 84 X-56 Weld 15.01" Surf 120' '1 . - ` 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' ' „ p: y,W1 4 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958" Surf 9,213' S r -, .,',11,.,I,, a, tr • i 4A "rr 4, 7 • . ;t JEWELRY DETAIL No. Depth ID OD Item 101 1 1 1,298' 3.958" 6.875" Baker Swell Packer t 2 9,054' 4.500" CIBP w/5'of cement 02/01/18 7_5/8" w ,. ,s,,; :- s 417 ' PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status ;'+' , T142 8,843' 8,862' 7,585' 7,604' 19' 6 12/14/17 Open tt. ' T142 8,843' 8,862' 7,585' 7,604' 19' 6 11/23/17 Open • �' " 1146 9,021' 9,035' 7,762' 7,775' 14' 6 09/11/17 Open + 1146 9,037' 9,045' 7,777' 7,785' 8' 6 08/31/17 Open 74t41 ' T146 9,042' 9,055' 7,782 7,795 13' 6 09/11/17 Isolated 6-3/4" T146 9,056' 9,076' 7,795 7,815 20' 6 08/25/17 Isolated Hole i � 4 ,_. T146 9,056' 9,076' 7,795 7,815 20' 6 08/08/17 Isolated r wA T146 9,072' 9,080' 7,811 7,819 8' 6 09/11/17 Isolated RA@5,490' • ,, d RA @ 6,490' •vv, 1,4 At "' : "' I OPEN HOLE/CEMENT DETAIL RA @ 7,500' �, 0`-'. .. .. 9-7/8"hole.100 BBL(226 sx)of 12 ppg Type I/II lead and 39.5 BBLs(181sx)15.4 ppg 7-5/8" + Class G tail. 100%returns throughout,51 bbls of lead to surface. 5/14/17 4-1/2" 6-3/4"hole.240 bbls(675sx)12.2 Type I/II and 35.2 bbls(160 sx)15.3 ppg Class G tail.100%returns.Trace volume of spacer to surface.Est.TOC±338'MD. RA @ 8,496' a i 44 ',: ai' y .%� T142 Note: Fish @ 9,061'01/31/18 consists of: TOF @ 9,061' 4,4.or Weatherford WRP w/catcher sub,wire and LIB 01/31/18 1 +` +er = _ . 2 1146 4•" r.° , 4 "_1/2, e. ., �" r,..IF PBTD=9,049'/PBTVD=7,789' TD=9,221'/TVD=7,958' Updated by DMA 02-13-18 21 70 63 RECEIVED JUL 19 2017 AOGCC Kalotsa 4 50-133-20665-00-00 Ninilchik Field Kenai Peninsula Borough, Alaska Provided by: CANRIG Approved by: Jacob Dunston Compiled by: Ralph Winkelman Eric Andrews Distribution Date: July 15, 2017 Kalotsa 4 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary ..................... 1.2 Crew.. ............................................. 2 GENERAL WELL DETAILS .................. 2.1 Well Objectives ............................... 2.2 Hole Data ........................................ 2.3 Daily Activity Summary ................... 3 GEOLOGICAL DATA ............................. 3.1 Lithostratigraphy ............................. 3.2 Lithology Details ............................. 3.3 Sampling Program .......................... 4 DRILLING DATA .................................... 4.1 Surveys. ................................ ........ 4.2 Bit Record ....................................... 4.3 Mud Record .................................... 4.4. Drilling Progress ............................. 5 SHOW REPORTS ................................. 6 DAILY REPORTS .................................. Enclosures 2" / 100' Formation Log (MD/TVD) 5" / 100' Formation Log (MD/TVD) 2" / 100' LWD Combo Log (MD/TVD) 2" / 100' Drilling Dynamics Log (MD/TVD) 2" / 100' Gas Ratio Log (MD/TVD) Final Data CD CANRIG 2 2 2 3 3 4 5 7 7 8 ..... 22 ..... 23 ..... 23 ..... 27 ..... 28 ..... 29 ..... 30 ..... 31 Kalotsa 4 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment T e /Position Total Downtime Comments in Computers — Surface Logging g (3) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 20 Ditch gas QGM gas trap; Flame ionization total gas & chromatography. >1 18 Hook Load / Weight on bit WITS from Pason 15 Lee Ann Rasher Mud Flow In Calculated value derived from Strokes/Minute and Pum Output 0 10 Mud Flow Out WITS from Pason " 16 Pit Volumes, Pit Gain/Loss WITS from Pason " Pump Pressure WITS from Pason " Pump Stroke Counters 2 WITS from Pason " Rate of Penetration Calculated from Pason " RPMWITS from Pason " Torque WITS from Pason " WITS To/ From Pason Rigwatch Remote HP Compaq) 1.2 Crew Mud Logging Unit Type: Arctic Mud Loaaina Unit Number: ML038 Logging Geologists Years' Da sZ Sample Catchers/Loggers Years Da sz Allen Odegaard 20 4 Garnet Knopp >1 18 Ralph Winkelman 27 15 Lee Ann Rasher 5 3 Marquel Mosebay 10 3 Brendon Schmidt >1 16 Eric Andrews 5 17 Years' experience as Mudlogger .2 Days at wellsite between rig up and rig down of logging unit. CANRIG Kalotsa 4 2 GENERAL WELL DETAILS 2.1 WellObiectives Kalotsa #4 is an S-shaped directional grassroots development well to be drilled off of the Kalotsa pad. Reservoir analysis and subsurface mapping has identified an optimal location for infill development of the Upper Tyonek sands, as well as an area with little to no production in the Middle and Upper Beluga sands. The base plan is a directional wellbore with a kickoff point at 500' MD. Maximum hole angle will be 53°. TD of the well will be 8922' MD/ 7661' TVD, ending at 120 inclination. The vertical section will be 3613'. Operator: HILCORP ALASKA, LLC Well Name: Kalotsa 4 Field: Ninilchik Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Rance Pederson, Robert Wall , Clint Montague, Adam Dorr Location: Surface Coordinates 2281' FSL, 481' FWL, Sec 7, T1 N, R13W, SM, AK Ground ( Pad ) Elevation 126.5' AMSL Rotary Table Elevation 18' RKB — 144.5' AMSL Classification: Development — Gas API #: 50-133-20665-00-00 Permit #: 217-063 Rig Name/Type: Saxon 169 / Land / Double Spud Date May 15, 2017 Total Depth Date: May 27, 2017 Total Depth 9221'MD/ 7958.24'TVD Primary Targets Tyonek 6 521 VMD/ 4040'TVD, Tyonek 110 8467'MD/ 7217'TVD, Tyonek 140 8745'MD/ 7489'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 Halliburton CANRIG Kalotsa 4 2.2 Hole Data Hole Section Max De th TO Formation MW PP9 Dev 'inc Csg Did Shoe Depth LOT MD R TVD ft MD ft TVD ft 9 7/8" 1502' 1395.17' Beluga 9.20 44.08 75/8 1491.4' 1387.9' 13.5 6'/:' 9221' 7958.24' Tyonek 9.35 8.87 4 Y:" 9212' 7949' NA Kalotsa 4 2.3 Daily Activity Summary May 14, 2017: Rig up mudlogging unit May 15, 2017: Pick up & racked back 50 stands of 4.5" drill pipe, 9 joints of heavy -weight drill pipe & jars; pick up PDC bit & motor, run in hole & tagged @ 112'; drilled to 274'& had to back ream to conductor shoe; pulled out of hole & looked at bit—bit had multiple chips on cutters; run in hole & clean up hole; drilled another stand down to 341'; circulate bottoms up twice & back reamed out of hole; pick up the MWD tools, sources, motor, & new bit; trip back in & drill ahead to 479'. May 16, 2017: Drilling/sliding from 479' to 11,502% pumped a 20 bbl Hi -Vis sweep; MAD passed out of hole to conductor shoe for logs; finishing laying down bottom hole assembly at report time. May 17, 2017: Lay down tools, R/U casing equipment for 7 5/8" Casing run, Test float equipment, RIH with 7 5/8" Casing, Run casing string to 1491', land hanger, R/U cement equipment, Cement casing in place, R/D cement equipment, Install pack off, Nipple down conductor, install well head, Hang BOP, Nipple up DSA, Nipple up BOP while cleaning pits, Continue to Nipple up BOP at report time. May 18, 2017: Continue to nipple up BOP, install choke valve, R/U equipment on Rig for drilling while cleaning pits. Center BOP stack, Remove casing bails and elevators, install drilling bails and elevators, P/U test joint and set wear busing, P/U drill pipe, rack back, and strap every 20 joints in derrick. Install test plug/Fill BOPE & choke manifold with water. Begin pressure testing BOPE. May 19, 2017: Testing BOPE, attempt shell test, leaking, remove test plug, check seals, still bleeding off leak at test joint, check threads reinstall torque to 5000, Continue testing BOPE, R/D testing equipment, M/U 6 %" BHA, RIH, drill out shoe track plus 20' to 1522', Displace mud, perform FIT test to 13.5ppg, Drill ahead new formation. May 20, 2017: Drilled ahead from 1522' to 2535', pumped sweep, and circulated out of the hole to 1496' as a cleanout run. Circulated, and picked up pipe from 1963' to 2501'. Washed stand down from 2501' to 2535' and commenced drilling to 2794' at midnight depth. May 21, 2017: Continued Drilling from 2794' to 3530', picked up, and rotated off bottom. Pumped and circulated a sweep before pulling out of hole from 3530' to 2754'. Continued pulling from 2754' to 2515' while back reaming. Serviced rig and then picked up 22 joints of pipe from 2501' to 3154'. Ran into hole with 6 stands from 3154' to 3530' and continued drilling ahead to 4091'. May 22, 2017: At 4091', picked up and pumped a high -viscosity sweep. Continued drilling ahead from 4901' to 4527', circulated and monitored well before pumping another sweep. Pulled out of hole from 4527' to 3830', back reamed from 3830' to 3706', circulated sweep, conditioned mud and circulated. Continued back reaming from 3645' to 1663' and performed flow check. Conditioned mud and circulated pump sweep. Continued pulling out of hole from 1663' to 174'. Laid down MWD tool, removed sources, and downloaded data. May 23, 2017: Picked up MWD Tool, shallow pulse tested, loaded sources, and began running into the hole from 481' to 2680'; installing turbo every 5 stands. Circulated a bottoms up with 1991 units of gas, and continued running into hole from 2680' to 4480. Washed and reamed from 4480' to 4502', circulated a bottoms up and began drilling from 4521' to 5316'. May 24, 2017: Continued drilling from 5316' to 5518', pumped a high viscosity sweep, and pullout out of the hole for a wiper trip from 5518' to 4466'. Serviced Rig, and began running back into the hole from 4466' to 5518'. Circulated bottoms up, pumped a high viscosity sweep, and continued drilling from 5518' to 6634'. CANRIG J Kalotsa 4 May 25, 2017: Drilled from 6634' to 6654', circulated bottoms up, pumped a tandem low viscosity sweep/high viscosity sweep, and began pulling out of the hole for a wiper trip. Pulled out of the hold from 6654' to 5458' working through tight spots. Serviced rig, ran back into the hole from 5458' to 6654', washing and reaming the last stand to the bottom. Drilled from 6654' to 7102', pumped a sweep, and continued drilling from 7102' to 7580'. May 26, 2017: Drilled ahead from 7580' to 7787', picked up, pumped a high viscosity sweep, and circulated out of the hole from 7787' to 6719'. Serviced rig and ran back into the hole from 6719' to 7787'. Drilled ahead from 7787' to 8223', picked up and circulated new mud into the system. Continued drilling from 8223' to 8355'. May 27, 2017: Drilled from 8355' to 8465, pumped a high viscosity sweep, and continued drilling from 8465' to 9221' (TD). Picked up off bottom, pumped sweep, and circulated the hole clean. Began pulling out of the hole from 9221' to 5313'. May 28, 2017: Continued pulling out of the hole from 5313' to 4939', reaming as needed and laying down spiral gliders. Circulate bottoms up, and back ream from 4939' to 4545'. M.A.D. Pass from 4545' to 2089'. May 29, 2017: Continued M.A.D. Pass from 2089' to 1540' and pulled out of the hole from 1540' to 141'. Downloaded MWD data, laid down BHA, slip and cut, and serviced rig. Picked up clean out BHA and ran into hole to 8602' and circulated out gas. May 30, 2017: Shut in well; recording shut in pressures for 30 minutes, circulated bottoms up, washed and reamed from 8661' to 9221'. Conditioned mud and circulated the mud weight from 9.4 to 9.5 then pumped a high viscosity sweep. Performed a flow check, pulled out of hole from 9221' to BHA, and began preparation for shell test. Performed shell test, rigged down test equipment and began preparation for BOP test. May 31, 2017: Perform BOP test, rig down test equipment, and rig up E -line. Run in hole with E -line dummy and tag 8430', pull out of hole, and rig down dummy run. Make up XPT, run in hole with E - wireline, record pressures, pull out of hole, and change out logging tools. June 1, 2017: Finished changing out logging tools, ran in hole from surface to 8430', and wireline logged from 8430' to surface. Picked up side wall coring tools and ran in hole from surface to 7888'. Took various side wall cores (37 Total) and began pulling out of the hole. June 2, 2017: Pulled out of the hole, laid down logging tools and wireline equipment, made up clean out BHA and began running in hole. Run in hole to TD at 9221', circulate bottoms up, pump a high viscosity sweep, and circulate out. Wash out of hole from 9221' to 8911', continue pulling out of the hole on elevators to 8600', pump a slug, and pull out of hole from 8600' to 7975'. Continue pulling out of hole to 5079' while laying down drill pipe. June 3, 2017: Finished laying down drill pipe and prepared for running in casing. Began running production casing into hole from 127' to 4160'. June 4, 2017: Finish running casing to 9212'. Pump cement job. Released from rig pad 6 CANRIG Jf Kalotsa 4 GEOLOGICAL DATA 3.1 Lithostratioraphv Kalotsa 4 - Tops picked by Hilcorp, Geologist, Jacob Dunston FORMATION PROGNOSED ACTUAL MD ft TVD ft SSTVD ft MD ft TVD ft SSTVD ft Primary T6 5211 4040 -3896 5,209 4,038 -3,893 T110 8467 7217 -7073 8,446 7,195 -7,050 T140 8745 7489 -7345 8,719 1 7,463 -7,318 Secondary T83 8007 6768 -6624 8,005 6,765 -6,620 T90 8158 6915 -6771 8,164 6,921 -6,776 CANRIG Kalotsa 4 3.2 Litholoav Details As per Hilcorp direction, a Canrig/NDS-provided full service mudlogging program, with lithology descriptions of interval -collected rock cuttings samples in the Beluga and Tyonek Formations, was initiated at the 6 3/4" production interval at 1502'. The Kenai Group formations of Alaska's Cook Inlet Basin, which include the Sterling, Beluga, and Tyonek, were deposited in a variable -energy fluvial system within a large closed fore -arc basin. The stratigraphic column consists of very dominant thin to massive sections of sandstone and claystone- siltstone, which are interrupted by extensively -distributed thinner zones of coal and carbonaceous rocks, locally to generally abundant thin layers of original and re -deposited volcanic ash, and minor beds of basal or modal conglomerate. Gradational upward -fining sequences and bi-modal zones are abundant within the sandstones. Stratovolcanoes, perpetually forming along the fore -arc's margins; produced abundant widely -distributed deposits of vitric air fall volcanic ash; which became a major directly -derived source, and/or a consistent lithogenic influence, for all Tertiary soft -sediment rocks in the Cook Inlet Basin. Note that the special modifying term "tuffaceous" in Canrig/NDS Lithology Descriptions was created to address the diversity of volcanic -origin rocks in the Cook Inlet basin, and its use may include everything from discernible micro -shard concentrations of disaggregated volcanic glass to rare layers of vitric ignimbrite. Tuffaceous Siltstone/ Claystone (1530' -1560) = light gray to medium gray; stiff tenacity, occasionally mushy; brittle to sectile tenacity; irregular fracture; tabular to wedgelike cuttings habit; greasy, earthy luster; smooth, slightly silty texture; trace coal, and other dark lithics. Tuffaceous Claystone (1560'- 1590) = medium gray to medium dark gray; plastic clay properties; stiff consistency; brittle to sectile tenacity; irregular, occasionally hackly fracture; tabular to wedgelike cuttings habit; greasy, earthy luster; smooth and clayey texture; often suspended dark lithics. Sand (1590'- 1620') = medium dark gray to dark gray; dominantly quartz/feldspar; fine to medium grain size; well sorted; subangular to subrounded, occasionally angular; moderate to high sphericity, trace micas; trace light greed, dark green, light brown, and black lithics. Coal (1620' - 1650') = dark brown to black; dense and brittle; blocky, often hackly fracture; wedgelike cuttings; resinous luster; matte texture; thin structure; moderate outgassing observed. Tuffaceous Claystone (1660'- 1710') = light gray to gray; PDC disaggregated; stiff but also mushy; irregular, earthy fracture; tabular cuttings habit; dull, greasy luster; smooth and clayey texture; trace mica; trace siltstone. Sand (1710'- 1760) = medium dark gray to dark gray; feldspar/quartz mix; upper very fine to upper fine sand grains; well to very well sorted; round to subrounded, occasionally subangular; moderate to high sphericity; dominantly frosted grains; tuffaceous material abundant; trace mica; rare course sized grains; black, dark gray, dark bluish gray, light yellow lithics also present. Tuffaceous Claystone (1770'- 1810') = light gray to medium gray; adhesive clay properties; mushy and pasty; malleable tenacity; irregular fracture; mostly no definable cuttings habit but occasionally tabular and wedgelike; greasy, dull luster; silty, slightly gritty texture; trace coal and other dark lithics. Tuffaceous Claystone (1810' - 1860') = light gray to medium gray with olive gray hues; stiff consistency; brittle, sometimes crumbly tenacity; irregular fracture; tabular to wedgelike cuttings habit; greasy and earthy luster; smooth and clayey, occasionally silty with larger floating lithics, common PDC disaggregated sample cuttings. CANRIG Kalotsa 4 Tuffaceous Claystone (1860' -1910') = dark gray to olive gray and dark olive gray; adhesive clay properties; tacky to pasty consistency; malleable tenacity; irregular earthy fracture; tabular to blocky cuttings habit; dull, earthy luster; silty to gritty texture, often suspended lithic particles; trace tuffaceous siltstone. Sand (1920'- 1960') = dark gray to olive gray with light gray hues; quartz and feldspar dominant; upper very fine to fine grains; well sorted; subangular to subrounded; moderate sphericity; abundant tuffaceous material, trace coal, dark gray, dark green, and brown lithics. Tuffaceous Claystone (1960'- 2010') = dark olive gray to olive gray with gray hues; cohesive and adhesive clay properties; mushy and pasty, occasionally stiff; malleable to sectile tenacity; irregular fracture; tabular to wedgelike cuttings habit; greasy luster; silty texture, often suspended black lithics; trace Siltstone. Tuffaceous Claystone/ Tuffaceous Siltstone (2010'-2070') = medium light gray to light gray with trace very light brownish gray secondary hues; shapeless, irregular cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; very soluble; very soft; poor cohesiveness and adhesiveness; non calcareous; trace thin coal beds; no outgassing; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (2070'- 2130') = medium gray to medium light gray overall with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black and light greenish gray; very fine upper to fine upper, dominantly fine lower; angular to subangular; moderately well to very well sorted; unconsolidated; non calcareous; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (2130' - 2200') = light gray to very light gray with medium light gray secondary hues; very soft; shapeless, amorphous to globular cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; very soluble; poor cohesiveness; poor to fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments, trace very thin coal beds throughout interval; no outgassing observed. Sand (2200'- 2260') = medium gray to medium light gray overall with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black and light greenish gray; very fine upper to fine upper, dominantly fine lower; angular to subangular; moderately well to very well sorted; unconsolidated; non calcareous; trace thin coal beds throughout interval; no outgassing observed. Tuffaceous Claystone/ Tuffaceous Siltstone (2260'- 2320') = medium light gray to light gray with trace very light brownish gray secondary hues; shapeless, irregular cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; very soluble; very soft; poor to fair cohesiveness; fair adhesiveness; non calcareous; trace thin coal beds throughout interval; no outgassing observed; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (2320'- 2370') = medium gray to medium dark gray with individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine upper to lower; angular to subangular; moderately well sorted; unconsolidated; non calcareous; trace thin coal beds; no outgassing observed. Tuffaceous Claystone/ Tuffaceous Siltstone (2370' - 2410') = medium to medium light gray; very soft; irregular to shapeless cuttings; silty to clayey texture; dull to earthy luster; hydrophilic; very soluble; poor adhesiveness and cohesiveness; non calcareous. CANRIG Kalotsa 4 Coal/ Carbonaceous Shale (2410'- 2460') = black with brownish black secondary hues; firm to moderately hard and brittle; flaky to platy to scaly; planar fracture dominant; smooth texture; resinous to earthy luster; poorly developed commonly grading to carbonaceous shale; present as very thin beds in dominantly claystone formation; sub bituminous; no outgassing observed. Sand (2460' - 2520') = medium gray to medium light gray overall with individual grains dominantly medium to dark gray, clear to translucent quartz and volcanic glass, black and light greenish gray; very fine upper to fine upper, dominantly fine lower; angular to subangular; moderately well to very well sorted; unconsolidated; non calcareous. Sand (2520'- 2590') = medium gray to medium light gray with a weak salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass very fine upper to trace coarse upper, dominantly fine; angular to subangular; moderately well sorted, unconsolidated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (2590' - 2660') = light gray to very light gray with medium light gray secondary hues; very soft; shapeless, amorphous to globular cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; very soluble; poor cohesiveness; poor to fair adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments; trace very thin coal beds throughout interval; no outgassing observed. Tuffaceous Claystone (2660'- 2710') = medium dark gray to olive gray, with light gray hues; lumpy, mushy consistency; malleable to sectile tenacity; irregular fracture; tabular to blocky, dominantly shapeless cuttings habit; greasy, dull luster; clayey to slightly silty texture; hydrophilic; trace brown and black lithics suspended in claystone; non calcareous. Sand (2720' - 2760') = medium dark gray to dark gray with light gray hues; quartz and feldspar dominant; lower fine to lower medium sand grains; well to very well sorted; subangular to subrounded; moderate to high sphericity; dark gray, black, brown, medium dark yellow, white frosted, and translucent lithics also present; unconsolidated; non calcareous. Tuffaceous Claystone (2770'- 2800') = medium dark gray to dark gray; adhesive and cohesive clay properties; expansive; mushy and pasty consistency; malleable tenacity; irregular fracture; shapeless cuttings habit, dull, earthy luster; silty, slightly gritty texture; trace brown and black lithics; non calcareous. Tuffaceous Claystone (2820'- 2850') = gray to medium dark gray with dark gray hues; adhesive, poor cohesive clay properties; pasty and mushy consistency malleable tenacity; irregular fracture; shapeless cuttings; dull, earthy luster, silty to gritty texture; black and brown suspended lithics; non calcareous. Tuffaceous Claystone (2860'- 2900') = light gray to medium gray; poor adhesive and cohesive clay properties; expansive; pasty to tacky consistency; malleable tenacity; irregular fracture; shapeless cuttings habit; dull, earthy luster; silty texture with suspended black lithology; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (2900' - 2960') = gray to medium dark gray with light gray hues; adhesive and expansive clay properties; stiff to mushy and pasty; malleable to sectile; irregular fracture; tabular to wedgelike cuttings habit; greasy, dull luster; smooth to slightly silty texture; hydrophilic; trace dark brownish black microthin carbonaceous laminations and suspended fragments; no outgassing observed; non calcareous. Tuffaceous Claystone (2970'- 3050) = medium dark gray to olive gray with light gray hues; poor cohesive clay properties; moderate adhesive clay properties; expansive; dominantly mushy and pasty, occasionally stiff consistency; malleable tenacity; irregular fracture; dominantly a shapeless cuttings habit, sometimes tabular; dull, earthy luster; silty to slightly gritty texture with suspended black and brown lithics; reacts moderately with 10% HCL. 10 CANRIG Kalotsa 4 Tuffaceous Claystone/ Tuffaceous Siltstone (3060' - 3120') = medium dark gray to dark gray to dark olive gray; adhesive and plastic clay properties; expansive; clumpy to pasty, occasionally stiff consistency; malleable to sectile; irregular fracture; dominantly round, oval cuttings, occasionally tabular cuttings habit; dull, earthy luster; clayey to slightly silty; suspended black lithics; olive gray siltstone with trace microthin carbonaceous laminations; no outgassing observed; weak sample reaction to HCL. Tuffaceous Claystone (3130' - 3180') = medium dark gray to dark gray with olive gray hues, plastic clay properties; moderately adhesive; expansive; stiff to pasty consistency; sectile to malleable tenacity; irregular earthy fracture; wedgelike to often shapeless cuttings habit; greasy, dull luster; silty luster; bedded with very thin coal throughout interval; no outgassing; non calcareous. Sand (3190'- 3230) = medium dark gray to light gray with dark gray hues; quartz and feldspar dominant; upper very fine to upper fine grains; well to very well sorted; subangular to subrounded; moderate to high sphericity; black, gray, whitish yellow lithics observed; unconsolidated; non calcareous. Tuffaceous Claystone (3240' - 3290') = medium dark gray to dark gray with olive gray hues; moderate adhesive clay properties; expansive; dominantly mushy pasty, but also rare stiff consistency; malleable tenacity; irregular fracture; massive shapeless cuttings habit, occasionally tabular to wedgelike; dull, earthy luster; smooth to silty texture; occasional black carbonaceous laminae, non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (3300'- 3330') = light gray to gray with dark gray and olive gray hues; plastic clay properties; stiff consistency; sectile to brittle tenacity; irregular, earthy fracture; tabular to wedgelike cuttings habit, dull, earthy luster; smooth but dominantly gritty texture with suspended carbonaceous fractures; trace microthin carbonaceous laminae; common black lithics; non calcareous. Tuffaceous Claystone (3360' - 3400') = medium gray to medium dark gray; moderate adhesive clay properties; expansive; clumpy to curdy consistency; malleable to sectile tenacity; irregular fracture; massive cuttings habit; dull, earthy luster; silty to gritty texture; trace coal and siltstone; no outgassing. Sand (3400' - 3450') = medium dark gray to olive gray with dark gray hues; quartz, feldspar, dark lithics mix; very fine to fine grains, occasionally medium sized grains; moderate to well sorted; subrounded to subangular; moderate to high sphericity; frosted, translucent, dark gray, dark green, reddish brown lithics; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (3450' - 3520') = medium gray to medium light gray with light gray secondary hues; very soft and sticky; shapeless globular cuttings; silty to clayey texture, dull, earthy to greasy luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firm fragments; trace very thin coal beds. Sand (3520'- 3590') = medium gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated with trace dark gray sandstone; hard; very fine grain; moderate to very calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (3590' - 3650') = medium to medium light gray with very light brown to light brownish gray secondary hues; very soft; sticky; shapeless, amorphous cuttings; silty to clayey texture; dull to greasy luster; curdy to pasty; hydrophilic; very soluble and moderately expansive, poor cohesiveness; poor to fair adhesiveness; non calcareous; trace very thin coal beds; no outgassing observed. 11 CANRIG Kalotsa 4 Coal/ Carbonaceous Shale (3650'- 3710') = black with brownish black secondary hues very firm to hard and brittle; scaly to flaky, occasionally massive; blocky to platy; planar fracture dominant; smooth to matte texture; resinous to slightly earthy luster; sub bituminous to bituminous; coal occasionally grades to carbonaceous shale; earthy; firm; no to weak trace outgassing bubbles observed; present as very thin beds in dominantly claystone formation. Tuffaceous Claystone/ Tuffaceous Siltstone (3710' - 3770') = medium gray to medium light gray with light gray secondary hues; very soft and sticky; shapeless globular cuttings; silty to clayey texture; dull, earthy to greasy luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace to common thin coal beds throughout interval; no outgassing observed. Sand (3770'- 3830') = medium gray with salt and pepper appearance, individual grains dominantly medium to dark gray, black, clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated; trace very thin coal beds throughout interval; no outgassing. Tuffaceous Claystone/ Tuffaceous Siltstone (3830'- 3900') = medium gray to medium light gray with light gray secondary hues; very soft and sticky; shapeless globular cuttings; silty to clayey texture; dull, earthy to greasy luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments; trace to common very thin coal beds throughout interval, no to very weak trace outgassing bubbles. Tuffaceous Claystone (3900' - 3960') = medium gray to medium dark gray with light gray secondary hues; poor cohesive properties; moderately adhesive; hydrophilic; very soluble; expansive; clumpy, pasty to mushy consistency; malleable to sectile tenacity; irregular fracture; massive, shapeless cuttings habit; silty to clayey texture; bedded with thin coal seams; very weak outgassing. Tuffaceous Claystone/ Tuffaceous Siltstone (3960' - 4020') = medium gray to medium dark gray with light gray and olive gray secondary hues; cohesive and adhesive clay properties; clumpy, pasty consistency; malleable tenacity; irregular fracture; tabular to shapeless cuttings habit; dull, earthy luster; dominantly smooth to slightly silty texture, often blackish brown suspended carbonaceous fragments; trace microthin carbonaceous laminae; no outgassing; very weak reaction to 10% HCL in sample. Tuffaceous Claystone (4030'- 4070) = medium gray to medium dark gray; moderately adhesive; hydrophilic; moderately expansive; lumpy to stiff consistency; malleable to sectile tenacity; irregular fracture; tabular to wedgelike, often shapeless cuttings habit; greasy, earthy luster; clayey to silty texture; trace black carbonaceous fragments; no outgassing. Coal/ Carbonaceous Shale (4080'- 4110) = black to brownish black; moderately hard to hard, often very hard; pulverulent, crunchy tenacity; irregular, hackly and sometimes splintery fracture, wedgelike to elongated and occasionally bladed cuttings habit; resinous, sparkling luster; matte texture; thin structure; very weak outgassing. Sand (4160' - 4200') = medium dark gray to dark olive gray with dark gray secondary hues, quartz, feldspar, and dark lithic mix; very fine to fine sand grains; poor to moderately sorted; subrounded to subangular, occasionally well rounded; moderate to high sphericity; unconsolidated grains; translucent, opaque, light amber, dark gray, and carbonaceous lithics observed. 12 CANRIG Kalotsa 4 Tuffaceous Claystone/ Tuffaceous Siltstone (4200' - 4260') = medium dark gray to dark gray with dark olive gray secondary hues; moderately adhesive, hydrophilic; expansive; mushy and pasty, common stiff samples; malleable to sectile tenacity; irregular fracture; dominantly shapeless, common tabular cuttings habit; greasy to dull luster; clayey to silty texture; microthin carbonaceous laminae; no outgassing observed; weak reaction to 10% HCL. Tuffaceous Claystone ( 4270'- 4320') = medium dark gray to olive gray with light gray secondary hues; moderately cohesive and adhesive; expansive; hydrophilic; mushy and pasty; malleable tenacity; irregular, earthy fracture; tabular, dominantly shapeless cuttings habit, smooth to silty texture; black to brownish carbonaceous suspended fragments; trace to common thin coal beds throughout interval; no outgassing observed. Tuffaceous Claystone (4330'- 4380') = medium gray to medium dark gray with light olive secondary hues; adhesive clay properties; expansive; hydrophilic; curdy, pasty consistency; malleable to sectile; irregular fracture; tabular to globular cuttings habit; greasy, earthy luster; silty to slightly gritty texture; microthin carbonaceous laminae; brownish black suspended lithic fragments; no outgassing. Sand (4410' - 4450') = medium dark gray to dark gray with light gray secondary hues; quartz and feldspar dominant; upper very fine to upper fine, common upper medium sand grains; moderate to well sorted; subangular to subround, common angular; moderate to high sphericity; unconsolidated; light gray, dark green, grayish purple, dark yellow, white, and black lithics; trace tuffaceous sandstone; hard; fine to very fine grained; poor to moderate reaction to 10% HCL. Sand (4460' - 4520') = medium gray to medium dark gray with light gray secondary hues; quartz and feldspar dominant; clear to translucent and frosted; upper very fine to lower medium grain size; moderate to well sorted, subrounded to rounded; moderate to high sphericity; unconsolidated. Tuffaceous Claystone/ Tuffaceous Siltstone (4520'- 4630') = medium gray to medium light gray with very light gray secondary hues; shapeless, globular cuttings; very soft; silty to clayey texture; dull, earthy to slightly greasy luster; hydrophilic; very soluble; slight to moderately expansive; poor cohesiveness; 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; no outgassing bubbles observed. Coal/ Carbonaceous Shale (4630'- 4700') = black with brownish black secondary hues very firm to hard and brittle; scaly to flaky, occasionally massive; blocky to platy; planar fracture dominant; smooth to matte texture; resinous to slightly earthy luster; sub bituminous to bituminous; coal occasionally grades to carbonaceous shale; earthy; firm; no to weak trace outgassing bubbles observed, present as very thin beds in dominantly claystone formation. Sand/ Tuffaceous Sandstone (4700'- 4750') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass with trace dark liths; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; dominantly unconsolidated with trace ashy supported grains; very light gray to grayish white; very fragile; loosely supports sand grains; non calcareous. Tuffaceous Sandstone/ Sand (4750' - 4820') = very light gray to grayish white; very soft; fragile to pulverulent; moderate to very calcareous; acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, black and white; very fine upper to coarse lower, dominantly fine lower to medium lower; angular to subangular; fair to good sorting; very loosely consolidated to unconsolidated with ashy supporting matrix common. 13 CANRIG Kalotsa 4 Sand/ Tuffaceous Sandstone (4820'- 4890') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass with trace dark liths; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; dominantly unconsolidated with ashy supporting matrix; very light gray to grayish white; very fragile; loosely supports sand grains; non calcareous; trace thin coal beds throughout interval. Tuffaceous Sandstone/ Sand (4890'- 4950') = light gray to very light gray with abundant darker secondary hues; irregular shaped; soft to fragile and pulverulent; crunchy; sparkling; ashy matrix acts as dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine upper to medium upper, dominantly fine; angular to subangular; moderately well sorted; trace coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (4950' - 5010') = light to very light gray; soft to fragile; irregular shaped; silty to clayey to slightly gritty texture; dull luster; poor to fair cohesiveness; poor adhesiveness; moderately soluble; non calcareous; siltstone commonly grades between silty sandstone and sandy siltstone; soft; non calcareous; trace thin coal beds. Coal/ Carbonaceous Shale (5010'- 5070) = black with brownish black secondary hues very firm to hard and brittle; scaly to flaky, occasionally massive; blocky to platy; planar fracture dominant; smooth to matte texture; resinous to slightly earthy luster; bituminous, occasionally grading to carbonaceous shale; earthy; silty in part; weak trace outgassing bubbles observed. Sand (5070'-5120') = olive gray to dark olive gray with medium dark gray and light gray secondary hues; translucent to frosted quartz and feldspar; lower very fine to upper fine grains; moderate to well sorted; subangular to subrounded; moderate to high sphericity; trace sandstone; moderately hard to hard; tuffaceous matrix; trace carbonaceous material; very weak outgassing observed. Tuffaceous Siltstone/ Tuffaceous Claystone (5130' -5160') = medium dark gray to olive gray with brownish gray hues; PDC bit disaggregated; stiff consistency; brittle to crumbly tenacity; irregular, earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; clayey to silty texture; trace carbonaceous laminae structures in siltstone samples; trace thin coal beds; weak out gassing. Tuffaceous Sandstone/ Sand (5190'- 5250') = medium gray to medium dark gray with olive gray hues; fine to very fine grains; moderately to well sorted; subangular to subrounded; moderate sphericity; PDC bit disaggregated; firm friable to friable; clay mineral cement; tuffaceous matrix; floating, point contact, and long contact fabric; bedded with tuffaceous claystone, tuffaceous siltstone, and trace thin coals; trace carbonaceous fragments suspended in sandstones; non calcareous. Tuffaceous Siltstone (5250'- 5300') = brownish gray to medium gray with olive gray secondary hues; stiff consistency; PDC disaggregated; brittle to crumbly; irregular earthy fracture; tabular to wedgelike, often platy cuttings habit; dull, earthy luster; silty to clayey texture; rare trace thin carbonaceous laminae; trace carbonaceous fragments; non calcareous. Sand ( 5340' - 5370') = olive gray to brownish gray with light gray secondary hues; quartz and feldspar dominant; dominantly upper very fine to upper fine grains, with rare lower medium sized grains; moderately sorted; angular to subangular; moderate to high sphericity; unconsolidated; abundant carbonaceous material; trace dark gray, light gray, yellow, orange, brown lithics; bedded with tuffaceous sandstone; firm to firm friable; fine grained; coal beds common throughout interval; moderate outgassing observed. 14 CANRIG Kalotsa 4 Tuffaceous Sandstone/ Sand (5400' - 5460') = medium dark gray to dark gray with olive gray secondary hues; quartz and feldspar framework, upper very fine to lower fine sand grains; well to moderately sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; firm friable; clay mineral cement; tuffaceous matrix; floating, point contact fabric; trace carbonaceous fragments; unconsolidated sand; weak salt and pepper appearance; upper very fine to lower medium sand grains; poor to moderately sorted; subangular to subrounded; moderate to high sphericity. Coal/ Carbonaceous Shale (5460' - 5560') = black with brownish black secondary hues very firm to hard and brittle; scaly to flaky, occasionally massive; blocky to platy; planar fracture dominant with common conchoidal and birdeye fracture; smooth texture; resinous to slightly earthy luster; bituminous, occasionally grading to carbonaceous shale; earthy; silty in part; weak trace outgassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (5560' - 5640') = light gray to very light gray with light yellowish gray secondary hues; soft to slightly firm; irregular, shapeless cuttings; silty to clayey texture; dull, earthy luster; soluble; slight to moderately expansive; hydrophilic; poor cohesiveness and adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firm fragments; trace thin coal beds throughout interval; no to very weak trace outgassing bubbles observed. Sand/ Tuffaceous Sandstone (5640'- 5700') = light gray overall with a weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray and black; very fine lower to medium lower dominantly fine; angular to subangular; moderately well sorted; unconsolidated to very loosely supported with ashy matrix; soft; fragile; light gray to grayish white with scattered darker secondary hues; non calcareous. Coal/ Carbonaceous Shale (5700'- 5760') = black with brownish black secondary hues very firm to hard and brittle; scaly to flaky, occasionally massive; blocky to platy; planar fracture dominant with common conchoidal and birdeye fracture; smooth texture; resinous to slightly earthy luster; bituminous, occasionally grading to carbonaceous shale; earthy; silty in part; weak trace outgassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (6760'- 5840') = light gray to medium light gray with light yellowish gray and medium gray secondary hues; soft, mushy to moderately firm; irregular, shapeless to wedge shaped cuttings; silty to clayey texture; dull, earthy luster; soluble; slight to moderately expansive; hydrophilic; poor to fair cohesiveness and adhesiveness; trace dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments; non calcareous; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (5840' - 5900') = light gray to medium light gray with light yellowish gray and medium gray secondary hues; soft, mushy to moderately firm; irregular, shapeless to wedge shaped cuttings; silty to clayey texture; dull, earthy luster; soluble; slight to moderately expansive; hydrophilic; poor to fair cohesiveness and adhesiveness; non calcareous; trace siltstone commonly grades between sandy siltstone and silty sandstone. Sand/ Tuffaceous Sandstone (5900'- 5960') = light gray overall with a weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray and black; very fine lower to medium lower dominantly fine; angular to subangular; moderately well sorted; unconsolidated to very loosely supported with ashy matrix; soft; fragile; light gray to grayish white; non calcareous. 15 CANRiG Kalotsa 4 Coal/ Carbonaceous Shale (5960'- 6020') = black with brownish black secondary hues very firm to hard and brittle; scaly to flaky, occasionally massive; blocky to platy; planar fracture dominant with common conchoidal and birdeye fracture; smooth texture; resinous to slightly earthy luster; bituminous, occasionally grading to carbonaceous shale, earthy; silty in part; trace to common outgassing bubbles observed. Tuffaceous Siltstone/ Tuffaceous Claystone (6020'- 6090') = light gray to light olive gray with medium light gray secondary hues; very soft to slightly firm; irregular, rounded cuttings; silty to clayey texture, dull, earthy luster; moderate to very soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace light yellowish gray siltstone grades between sandy siltstone and silty sandstone; soft to fragile; irregular shaped; abundant coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (6090'- 6150') = medium light to light gray with light olive gray and light brownish gray secondary hues; soft to occasionally firm; irregular, shapeless cuttings; silty to clayey texture; dull luster; soluble; poor to fair cohesiveness and adhesiveness; non calcareous; abundant coal beds. Sand (6150' - 6210') = light gray with light yellowish gray secondary hue overall, individual grains dominantly clear to translucent quartz and volcanic glass; light gray and light greenish gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated with trace ashy matrix supported grains; soft to fragile; light gray; non calcareous; trace to common thin coals throughout; interval; no to trace outgassing bubbles. Coal/ Carbonaceous Shale (6210'- 6270') = black with brownish black secondary hues very firm to hard and brittle; scaly to flaky, occasionally massive; blocky to platy; planar fracture dominant with common conchoidal and birdeye fracture; smooth to matte texture; resinous to earthy luster; bituminous, occasionally grading to carbonaceous shale; earthy; silty in part; no outgassing bubbles. Tuffaceous Claystone/ Tuffaceous Siltstone (6270'- 6330') = medium light to light gray with light olive gray and light brownish gray secondary hues; soft to occasionally firm; irregular, shapeless cuttings; silty to clayey texture; dull luster; soluble; poor to fair cohesiveness and adhesiveness; non calcareous; abundant thin coal beds throughout interval; no to trace, weak outgassing bubbles observed. Tuffaceous Sandstone (6330'- 6390') = medium gray to medium dark gray with light gray secondary hues; quartz and feldspar dominant; upper very fine to lower fine grains, upper fine grains common; well to very well sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; friable to easily friable; clay mineral cement; tuffaceous matrix support; floating and point contact fabric; carbonaceous fragments suspended; abundant tuff; non calcareous. Sand/ Tuffaceous Sandstone (6420'- 6450') = medium gray to medium dark gray with light gray and dark gray secondary hues; quartz and feldspar dominant; weak to moderate salt and pepper appearance; tower very fine to upper fine and common lower medium grains, moderately sorted; subrounded; moderate to high sphericity; unconsolidated; light green, yellow, reddish orange, black, and brown lithics observed, common tuffaceous sandstone; light gray to medium gray; dominantly easily friable, non calcareous; common thin coals throughout interval; trace to moderate outgassing. Tuffaceous Sandstone/ Sand (6480'- 6540') = medium dark gray to dark gray with olive gray secondary hues; quartz and feldspar dominant; weak salt and pepper appearance; upper very fine to upper fine sand grains, common medium grains; well to very well sorted; dominantly subrounded to rounded, sometimes angular to subangular; moderate to high sphericity; PDC disaggregated; soft to easily friable; clay mineral cement; tuffaceous matrix; floating contact, point contact; trace thin carbonaceous laminae; common carbonaceous fragments; common thin coals throughout interval, weak outgassing bubbles. 16 CANRIG Kalotsa 4 Tuffaceous Siltstone (6580'- 6630) = medium dark gray to dark gray with olive gray secondary hues; curdy to curdy to pasty consistency; sectile tenacity, occasionally crumbly; irregular fracture; tabular to wedgelike and platy cuttings habit; dull to earthy luster; clayey to silty texture; non calcareous; coal common throughout interval; moderate outgassing. Coal (6630' - 6660') = black, pulverulent to crunchy; earthy, blocky to splintery fracture; bladed to flaky and often elongated; resinous, dull luster; smooth to matte, often mottled texture; thin structure; bedded with sandstones and siltstones; moderate outgassing observed. Tuffaceous Claystone (6700' - 6750) = olive gray to brownish gray; mushy to stiff consistency; sectile to crumbly tenacity; irregular, earthy fracture; tabular to platy and wedgelike cuttings habit; dull, earthy luster; smooth to often gritty texture; bedded with thin to moderately thick coal beds throughout interval; weak to moderate outgassing. Tuffaceous Sandstone/ Sand (6750'- 6840') = very light gray to grayish white with abundant darker secondary hues presenting a mottled appearance; soft to fragile and pulverulent; crunchy; irregular shaped; sparkling luster; non calcareous acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, black , light green to greenish gray; very fine lower to trace very coarse upper, dominantly fine lower to medium lower; angular to subangular; moderately well sorted; very loosely supported by ashy matrix. Coal/ Carbonaceous Shale (6840'- 6900') = black with brownish black secondary hues hard to brittle; flaky to platy; finely ground up cuttings; planar fracture dominant with scattered conchoidal and birdeye; smooth to matte texture; resinous to earthy luster, bituminous with trace coal grading to carbonaceous shale; firm silty texture; earthy luster; non calcareous; common to abundant outgassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (6900'- 6970') = light gray to very light olive gray with very light brownish gray secondary hues; very soft; fragile; irregular, sub wedge shaped to shapeless; silty to clayey texture; dull to earthy luster; very soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; trace dark brown to black microthin carbonaceous laminations and inclusions; abundant thin coal beds throughout interval; trace outgassing bubbles observed. Sand (6970' - 7030') = light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted dominantly disaggregated with trace ashy matrix supported grains; very light gray to grayish white; fragile to pulverulent crunchy; non calcareous; common to abundant thin coal beds throughout interval; no to trace, weak outgassing observed. Tuffaceous Sandstone/ Sand (7030'- 7100') = very light gray to grayish white with yellowish gray secondary hue and a weak mottled appearance; soft to fragile and pulverulent; crunchy, irregular shaped; sparkling luster; non calcareous; commonly acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, black , light green to greenish gray; very fine lower to medium upper, dominantly fine lower to upper; angular to subangular; moderately well sorted; loosely supported by ashy matrix. Tuffaceous Sandstone/ Sand (7100' - 7180) = very light gray to grayish white with abundant darker secondary hues presenting a mottled appearance; soft to fragile and pulverulent; crunchy; irregular shaped; sparkling luster; non calcareous acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, black , light green to greenish gray; very fine lower to medium upper, dominantly fine upper to lower; angular to subangular; moderately well to very well sorted. 17 CANRIG J Kalotsa 4 Coal (7180'- 7220') = black with brownish black secondary hues; very firm to hard and brittle; flaky to platy, massive planar fracture dominant with conchoidal and birdeye common; smooth texture; resinous to slightly earthy luster; very well developed; bituminous; abundant and prolonged outgassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (7220' - 7270') = light gray to very light olive gray with very light brownish gray secondary hues; very soft; fragile; irregular, sub wedge shaped to shapeless; silty to clayey texture; dull to earthy luster; very soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; non calcareous. Sand/ Sandstone (7270' - 7350') = very light gray to light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium upper, dominantly fine; angular to subangular; moderately well sorted; unconsolidated with trace sandstone; dark gray with a salt and pepper appearance; very fine to fine grain; well sorted; very hard to brittle; angular to subangular; moderate to very calcareous; trace to common coal beds throughout interval; strong outgassing observed. Tuffaceous Siltstone (7350' - 7400') = olive gray to brownish gray with medium dark gray hues; stiff consistency; crumbly to pulverulent, sometimes sectile tenacity; earthy fracture; platy to tabular and wedgelike cuttings habit; greasy, earthy luster; clayey to silty texture, often slightly gritty; common suspended fragments of carbonaceous material in siltstone sample; trace to moderate amounts of carbonaceous shale; brownish black; hard to very hard; common thin to moderately thick coal beds throughout interval; moderate outgassing observed. Tuffaceous Sandstone/ Sand (7460'- 7500') = medium gray to medium dark gray with light gray secondary hues; quartz and feldspar framework; lower fine to lower medium sand grains, occasionally upper medium grains; moderate to well sorted; subrounded to well rounded; moderate to high sphericity; PDC disaggregated; soft and easily friable to firm friable; clay mineral cement; tuffaceous matrix support; free floating, point contact, long contact fabric; non calcareous; common black carbonaceous fragments; unconsolidated sand grains; light gray; moderate salt and pepper appearance; dominantly quartz and feldspar; fine to medium grained; subangular to subrounded; light green, yellow, red, reddish orange lithics observed; bedded with coal; strong outgassing. Tuffaceous Siltstone (7560'- 7620') = olive gray to brownish gray with medium dark gray hues; stiff to a pasty consistency, crumbly to pulverulent; irregular earthy fracture; dominantly platy to tabular cuttings, occasionally wedgelike; dull, earthy luster; clayey to silty, very often gritty with suspended carbonaceous fragments and microthin laminae; non calcareous. Coal/ Carbonaceous Shale (7590' - 7620') = black to brownish black; PDC disaggregated; brittle to crunchy tenacity; splintery to hackly fracture; flaky, bladed, and scaly cuttings habit; resinous to sparkling luster; smooth to matte texture; thin structure; weak outgassing. Sand/ Tuffaceous Sandstone (7680'- 7740') = olive gray to medium gray with very light gray hues; dominantly clear to translucent quartz and feldspar; lower very fine to upper fine grains; well to very well sorted; subrounded to round; moderate to high sphericity; unconsolidated; trace reddish orange and yellow lithics; common black to brownish black carbonaceous fragments; abundant tuff; tuffaceous sandstone; very light gray to medium dark gray; very fine to fine grained; well sorted; subrounded; moderate to high sphericity; PDC disaggregated; soft to easily friable; clay mineral cement; tuffaceous matrix; floating grain to point contact fabric; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (7740' - 7820') = light gray to very light olive gray with very light brownish gray secondary hues; very soft; fragile; irregular, sub wedge shaped to shapeless; silty to clayey texture; dull to earthy luster; very soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; non calcareous. 18 CANRIG Kalotsa 4 Tuffaceous Sandstone/ Sand (7820'- 7900) = very light gray to grayish white with abundant darker secondary hues presenting a mottled appearance; soft to fragile and pulverulent; crunchy; irregular shaped; sparkling luster; non calcareous commonly acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium upper, dominantly fine upper to lower; angular to subangular; moderately well sorted; trace sandstone; salt and pepper appearance; fine to medium; grain supported; fragile and brittle; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (7900'- 7970') = light gray to very light olive gray with very light brownish gray secondary hues; very soft; fragile; irregular with trace PDC bit action shaped; silty to clayey texture; earthy luster; very soluble; hydrophilic poor to fair cohesiveness; poor adhesiveness; non calcareous; trace very light grayish white, ashy tuff; very fragile, trace thin coal beds throughout interval; no outgassing bubbles present. Tuffaceous Sandstone/ Sand (7970'- 8030') = very light gray to grayish white with abundant darker secondary hues; fragile and pulverulent; crunchy; irregular shaped; sparkling luster; non calcareous commonly acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium upper, dominantly fine upper to lower; angular to subangular; well sorted; abundant coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (8030'- 8100') = light gray to very light olive gray with very light brownish gray secondary hues; very soft; fragile; irregular, sub wedge shaped to shapeless, silty to clayey texture; dull to earthy luster; very soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds. Tuffaceous Sandstone/ Sand (8100' - 8160') = very light gray to grayish white; fragile and pulverulent; crunchy; irregular shaped; sparkling luster; non calcareous commonly acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium upper, dominantly fine upper to lower; angular to subangular; well sorted; scattered thin coal beds throughout. Sand/ Tuffaceous Sandstone (8160'- 8220') = very light gray with individual grains clear to translucent quartz and volcanic glass, trace light gray, dusky red and black; very fine lower to trace very coarse upper, dominantly fine upper to medium lower; angular to subangular; fair to good sorting; disaggregated with ashy matrix supported grains, very light grayish white; fragile to pulverulent; non calcareous. Tuffaceous Sandstone (8230' - 8280') = medium light gray to medium gray with medium dark gray secondary hues; quartz and feldspar framework; lower very fine to upper fine grains; moderate to well sorting, subrounded to round; moderate to high sphericity; PDC bit disaggregated; easily friable to firm friable; clay mineral cement; tuffaceous matrix support; floating grain to point contact fabric; trace siltstone, tuff, and carbonaceous fragments; non calcareous. Tuffaceous Siltstone (8300'- 8450') = dark gray to brownish black with olive gray secondary hues; PDC bit disaggregated; brittle to pulverulent tenacity; irregular, earthy fracture; tabular to wedgelike and occasionally platy; greasy to dull earthy luster; silty to slightly gritty texture; often carbonaceous microthin laminae or suspended fragments within the sample; non calcareous. Tuffaceous Siltstone (8370'- 8430') = olive black to brownish black with brownish gray and medium gray secondary hues, PDC bit disaggregated; brittle to crumbly and often pulverulent tenacity; earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; smooth to clayey, slightly gritty texture; rare hard to very hard red banded lithics; trace sandstone; common brownish black carbonaceous fragments; thin coal beds throughout interval; weak to moderate outgassing. 19 CANRIG Kalotsa 4 Coal ( 8430' - 8460') = black with trace brownish black hues; brittle to crunchy tenacity; blocky to hackly fracture; wedgelike, elongated, bladed, scaly cuttings habit; resinous luster, matte texture on sides, abrasive edges; moderately thick structure; weak to moderate outgassing. Tuffaceous Sandstone (8460' - 8520') = medium light gray to medium gray with medium dark gray secondary hues; quartz and feldspar dominant framework; lower very fine to lower fine, occasionally upper fine; well to very well sorted; subrounded to round to well rounded; moderate to high sphericity; PDC disaggregated; easily friable to firm friable, rarely moderately hard; clay mineral cement; tuffaceous matrix supported; dominantly floating contact, point contact common; trace reddish orange, dark yellow, pale yellow, grayish purple lithics observed; non calcareous. Sand/ Tuffaceous Sandstone (8580'- 8650') = medium gray to medium dark gray; quartz and feldspar framework; lower very fine to fine grains, occasionally lower medium to upper medium grains; poor to moderately sorted; subangular to subrounded; moderate to high sphericity; trace tuff; common black carbonaceous fragments; reddish orange, aqua, light gray, and yellow lithics; tuffaceous sandstone; light gray, moderate to strong salt and pepper appearance; friable to firm friable; fine grained; moderate to poorly sorted; subrounded; moderate sphericity; PDC disaggregated; clay mineral cement; floating grain support; tuffaceous matrix; non calcareous, common coal beds throughout interval; weak to moderate outgassing. Tuffaceous Siltstone (8650' - 8720') = brownish gray to medium dark gray and dark gray; brittle to crumbly tenacity; irregular, earthy fracture; tabular to wedgelike cuttings habit; dull, earthy luster; silty to gritty texture; trace carbonaceous fragments suspended in sample; trace sandstone; trace coal fragments; trace coal bedding throughout interval; no outgassing observed, Tuffaceous Sandstone (8720' - 8780') = medium dark gray to dark gray with olive gray and brownish gray secondary hues; dominantly quartz framework, trace feldspar; fine to very fine sand grains, moderate to well sorting; subangular to subrounded; PDC disaggregated; soft to easily friable, rarely firm friable; clay mineral cement; tuffaceous matrix support; floating, point contact, and long contact fabric observed; non calcareous. Coal (8780' - 8830') = black with brownish black secondary hues; very firm to hard and brittle; flaky to platy, massive planar fracture dominant with conchoidal and birdeye common; smooth texture; resinous to slightly earthy luster; very well developed; bituminous; abundant and prolonged outgassing bubbles observed. Sand/ Tuffaceous Sandstone (8830'- 8900') = very light gray overall with loose grain dominantly clear to translucent quartz and volcanic glass, light gray and light green, very fine lower to very coarse upper, dominantly fine lower to medium upper; angular to subangular; poorly sorted; disaggregated to very loosely ashy matrix supported; very light grayish white with subtle darker secondary hues, very soft and fragile; pulverulent crunchy; irregular shaped; sparkly; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (8900' - 8960) = light gray to light olive gray with light brown and brownish gray secondary hues; very soft; fragile; irregular, sub wedge shaped to shapeless; silty to clayey texture; dull to earthy luster; very soluble; hydrophilic; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace to common coal beds throughout interval. Tuffaceous Sandstone/ Sand (8960'- 9030) = very light gray to grayish white with faint darker secondary hues; fragile and pulverulent; crunchy; irregular shaped; sparkling luster; non calcareous commonly acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to coarse lower, dominantly fine upper to medium upper; angular to subangular; poor to fair sorting; scattered coal beds. 20 CANRIG Kalotsa 4 Sand/ Conglomeratic Sand/ Tuffaceous sandstone (9030'- 9090') = very light gray with individual grains dominantly clear to translucent quartz and volcanic glass with trace dark liths; very fine upper to very coarse upper, dominantly fine upper to medium upper; angular to subangular; poorly sorted; disaggregated to very loosely supported by ashy matrix white; very fragile; non calcareous; trace thin coal beds throughout. Tuffaceous Claystone/ Tuffaceous Siltstone (9090' - 9150') = light gray with light olive gray and light brownish gray secondary hues; soft to slightly firm; irregular shaped; silty to clayey texture earthy luster; moderately soluble; hydrophilic; poor to fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds throughout interval; no outgassing bubbles observed. Coal/ Carbonaceous Shale (9150'- 9221') = black with brownish black secondary hues very firm to hard and brittle; flaky to finely ground up cuttings; platy to blocky; planar fracture dominant with common conchoidal and birdeye; smooth texture; resinous luster; well-developed bituminous with occasional grading to a brownish black, earthy carbonaceous shale; abundant outgassing bubbles. 21 CANRIG Kalotsa 4 3.3 Sampling Program set Type and Purpose Interval Frequency Distribution 1502'— 2730' 2730'— 4050' Jacob Dunston A Washed and Dried 4050'— 5640'30, Hilcorp Alaska LLC Reference 5640'— 6900' 3800 Center Point Drive, Suite 100 6900'— 8700' Anchorage, AK 99508 8700'— 9221' 1502'- 2730' 2730'— 4050' Jacob Dunston B Washed and Dried 4050'— 5640'30, Hilcorp Alaska LLC Reference 5640'— 6900' 3800 Center Point Drive, Suite 100 6900'— 8700' Anchorage, AK 99508 8700'— 9221' 1502'- 2730' 2730'— 4050' Jacob Dunston C Washed and Dried 4050'— 5640'30, Hilcorp Alaska LLC Reference 5640'— 6900' 3800 Center Point Drive, Suite 100 6900'— 8700' Anchorage, AK 99508 8700'— 9221' 22 CANRIG J_ Kalotsa 4 4 DRILLING DATA 4.1 Surveys Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N(+), SO Departure (ft) E+,W_ Vertical Section Incr ft Dogleg Rate /100ft 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 196.87 0.25 295.62 196.87 0.17 -0.36 0.38 0.14 260.48 0.51 303.69 260.48 0.39 -0.72 0.77 0.41 323.54 0.77 297.82 323.53 0.74 -1.33 1.42 0.42 385.21 1.16 310.50 385.19 1.34 -2.17 2.33 0.72 447.10 3.44 301.31 447.04 2.71 -4.23 4.55 3.72 509.57 4.60 302.85 509.35 5.04 -7.94 8.52 1.87 572.45 6.31 302.77 571.94 8.28 -12.96 13.93 2.72 634.65 8.78 300.71 633.60 12.56 -19.92 21.38 3.99 697.24 11.02 297.52 695.25 17.76 -29.33 31.39 3.70 757.07 12.79 292.75 753.79 22.97 -40.51 43.15 3.38 819.00 15.09 289.57 813.90 28.32 -54.43 57.65 3.92 881.69 17.13 289.24 874.12 34.09 -70.84 74.67 3.25 944.58 20.10 287.63 933.71 40.42 -89.89 94.38 4.80 1005.77 23.58 286.12 990.50 47.01 -111.68 116.84 5.76 1068.60 26.84 285.94 1047.34 54.40 -137.40 143.30 5.19 1132.40 29.22 286.22 1103.65 62.70 -166.20 172.94 3.73 1195.99 32.52 287.28 1158.22 72.12 -197.44 205.13 5.27 1256.49 35.05 287.51 1208.50 82.18 -229.54 238.27 4.18 1318.72 38.08 288.47 1258.48 93.63 -264.79 274.71 4.95 1380.56 40.35 288.67 1306.39 106.08 -301.85 313.07 3.68 1442.68 43.19 288.49 1352.71 119.27 -341.07 353.67 4.57 1466.34 44.08 288.54 1369.84 124.45 -356.55 369.69 3.77 1562.08 46.64 289.29 1437.10 146.53 -420.97 436.43 2.73 1625.46 47.39 288.34 1480.32 161.49 -464.86 481.89 1.60 1718.84 53.88 289.44 1539.52 184.88 -533.12 552.61 7.02 1748.86 54.57 289.83 1557.07 193.07 -556.05 576.41 2.50 1810.46 54.25 289.72 1592.92 210.01 -603.19 625.35 0.53 1873.27 53.19 289.04 1630.08 226.82 -650.95 674.89 1.90 1936.36 53.90 288.66 1667.57 243.22 -698.97 724.64 1.23 1999.76 51.56 288.14 1705.96 259.15 -746.85 774.17 3.74 2060.86 52.07 288.22 1743.73 274.14 -792.47 821.36 0.83 2123.71 52.65 287.67 1782.12 289.47 -839.81 870.29 1.16 2185.61 1 52.96 286.73 1819.54 304.05 -886.92 918.89 1.31 2247.16 53.42 286.37 1856.42 318.08 -934.16 967.55 0.88 23 CANRIG r�J_ Kalotsa 4 Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section Incr ft Dogleg Rate /1008 2308.84 54.02 286.04 1892.92 331.96 -981.90 1016.69 1.08 2372.53 53.10 287.44 1930.75 346.71 -1030.97 1067.26 2.29 2433.86 53.27 286.92 1967.50 361.21 -1077.88 1115.65 0.73 2495.32 52.27 288.32 2004.68 376.01 -1124.51 1163.81 2.43 2559.35 52.81 287.75 2043.63 391.75 -1172.84 1213.78 1.09 2621.18 52.27 290.61 2081.24 407.87 -1219.19 1261.82 3.77 2683.82 52.19 290.80 2119.61 425.37 -1265.51 1310.02 0.27 2745.90 53.08 292.37 2157.29 443.53 -1311.38 1357.86 2.48 2807.55 53.80 291.60 2194.02 462.07 -1357.30 1405.80 1.54 2869.48 54.43 291.50 2230.32 480.50 -1403.97 1454.47 1.03 2931.87 55.12 290.78 2266.30 498.88 -1451.50 1503.98 1.45 2993.97 53.80 289.87 2302.40 516.43 -1498.88 1553.24 2.43 3055.65 53.35 288.84 2339.02 532.88 -1545.70 1601.80 1.53 3117.70 54.34 288.53 2375.64 548.94 -1593.16 1650.95 1.65 3180.78 52.48 288.03 2413.23 564.83 -1641.24 1700.69 3.02 3242.33 51.01 286.18 2451.34 579.05 -1687.43 1748.33 3.35 3305.01 49.56 285.56 2491.39 592.24 -1733.81 1796.02 2.44 3367.13 47.80 285.13 2532.40 604.58 -1778.79 1842.23 2.89 3429.61 46.67 283.69 2574.83 616.00 -1823.21 1887.76 2.47 3492.62 45.64 283.25 2618.48 626.59 -1867.41 1932.96 1.71 3551.99 45.90 282.88 2659.89 636.21 -1908.85 1975.30 0.63 3615.00 44.66 282.32 2704.23 645.98 -1952.54 2019.89 2.05 3677.88 43.87 281.31 2749.25 654.97 -1995.50 2063.65 1.69 3739.83 42.89 280.41 2794.28 662.99 -2037.29 2106.12 1.87 3803.47 41.78 280.16 2841.33 670.65 -2079.45 2148.93 1.77 3866.33 39.99 279.53 2888.85 677.68 -2119.98 2190.02 2.92 3927.79 38.45 278.90 2936.46 683.91 -2158.34 2228.86 2.59 3990.53 38.64 278.05 2985.54 689.67 -2197.01 2267.96 0.91 4052.39 37.92 275.94 3034.10 694.34 -2235.04 2306.27 2.41 4114.64 36.80 273.38 3083.58 697.42 -2272.68 2343.99 3.08 4176.99 35.63 271.74 3133.89 699.07 -2309.47 2380.69 2.44 4239.76 34.92 269.58 3185.14 699.49 -2345.71 2416.68 2.28 4301.54 33.76 267.04 3236.15 698.48 -2380.54 2451.07 2.99 4363.37 32.85 265.00 3287.83 696.13 -2414.40 2484.35 2.33 4424.75 32.29 263.82 3339.56 692.91 -2447.29 2516.54 1.38 4485.95 32.01 263.04 3391.37 689.19 -2479.64 2548.13 0.82 4535.64 32.35 262.96 3433.43 685.96 -2505.91 2573.76 0.70 4597.95 31.39 261.79 3486.35 681.60 -2538.52 2605.52 1.83 4659.5 30.05 261.28 3539.26 676.97 -2569.62 2635.76 2.21 24 CANRIG Kalotsa 4 Measured Depth Incl. Azim. True Vertical Depth ft Latitude (ft) N(+), S - Departure (ft) E(+), W _ Vertical Section Incr ft Dogleg Rate 01 ON) 4722.54 29.19 259.74 3594.05 671.84 -2600.35 2665.56 1.83 4788.11 28.62 259.00 3651.46 665.99 -2631.49 2695.69 1.02 4851.15 27.37 258.57 3707.12 660.24 -2660.51 2723.72 2.01 4851.15 27.37 258.57 3707.12 660.24 -2660.51 2723.72 2.01 4912.51 26.15 256.93 3761.91 654.39 -2687.51 1 2749.72 2.33 4975.88 23.34 255.99 3819.45 648.19 -2713.30 1 2774.49 4.47 5038.69 21.63 255.84 3877.49 642.34 -2736.60 2796.83 2.73 5104.71 20.17 255.92 3939.16 636.60 -2759.44 2818.73 2.22 5165.05 18.10 255.00 3996.17 631.64 -2778.59 2837.08 3.46 5227.12 17.29 257.14 1 4055.30 627.09 -2796.89 2854.64 1.68 5290.39 16.35 257.87 4115.86 623.13 -2814.76 2871.84 1.52 5352.61 15.40 259.64 4175.71 619.80 -2831.45 2887.96 1.70 5419.67 14.58 261.09 4240.48 616.89 -2848.55 2904.53 1.35 5480.65 13.09 263.81 4299.70 614.96 -2863.00 2918.61 2.66 5544.39 12.75 262.54 4361.82 613.27 -2877.15 j 2932.42 0.70 5609.21 12.95 261.96 4425.02 611.33 -2891.44 2946.33 0.38 5671.01 13.57 262.63 1 4485.17 609.43 -2905.48 2960.02 1.02 5737.89 13.41 263.30 4550.21 607.52 -2920.97 2975.12 0.33 5800.29 13.42 264.36 4610.91 605.96 -2935.36 2989.19 0.39 5863.51 12.83 258.98 4672.48 603.90 -2949.55 3002.99 2.14 5925.74 12.31 257.39 4733.21 601.13 -2962.81 3015.78 1.00 5988.01 12.37 257.68 4794.05 598.26 -2975.80 3028.29 0.14 6054.28 12.09 257.15 4858.81 595.20 -2989.50 3041.47 0.46 6117.14 11.77 256.96 4920.31 592.29 -3002.17 3053.66 0.50 6179.80 11.45 257.91 4981.69 589.54 -3014.48 3065.51 0.60 6243.04 11.47 257.37 5043.67 586.85 -3026.76 3077.33 0.17 6306.65 11.30 257.45 5106.03 584.12 -3039.01 3089.13 0.27 6369.03 11.52 257.10 5167.17 581.40 -3051.05 3100.71 0.37 6431.67 12.09 258.11 5228.49 578.65 -3063.57 3112.77 0.97 6494.40 11.66 257.25 5289.87 575.90 -3076.18 3124.91 0.75 6554.72 11.36 255.94 5348.98 573.11 -3087.89 3136.16 0.66 6617.95 11.22 260.02 5410.99 570.53 -3099.98 3147.82 1.28 6683.76 10.82 261.59 5475.59 568.52 -3112.40 3159.87 0.76 6746.77 11.30 262.34 5537.43 566.83 -3124.37 3171.52 0.80 6808.23 11.57 262.37 5597.66 565.21 -3136.45 3183.29 0.44 6869.55 11.32 261.05 5657.77 563.46 -3148.50 3195.00 0.59 6932.70 12.18 260.56 5719.59 561.40 -3161.19 3207.32 1.37 6999.63 12.09 260.44 5785.03 559.08 -3175.06 3220.78 0.14 7064.93 12.71 263.40 5848.80 557.12 -3188.94 3234.28 1.36 25 CANRIG J Kalotsa 4 Measured Depth ft Incl. Azim. True Vertical Depth ft Latitude (ft) N+, S- Departure (ft) E+, W_ Vertical Section Incr ft Dogleg Rate 0/100ft 7127.43 13.17 263.30 5909.71 555.50 -3202.84 3247.85 0.74 7190.09 13.27 260.53 5970.72 553.48 -3217.02 3261.65 1.02 7253.24 12.80 258.33 6032.24 550.87 -3231.02 3275.20 1.08 7316.65 12.73 259.93 6094.08 548.23 -3244.78 3288.49 0.57 7378.67 13.41 260.57 6154.50 545.86 -3258.61 3301.90 1.13 7441.98 13.36 260.81 6216.08 543.49 -3273.07 3315.93 0.12 7501.67 13.05 261.81 6274.20 541.43 -3286.55 3329.02 0.65 7564.91 12.17 259.61 6335.92 539.21 -3300.17 3342.24 1.58 7627.42 11.91 260.38 6397.05 536.94 -3313.01 3354.68 0.48 7690.08 12.11 261.72 6458.33 534.91 -3325.89 3367.18 0.55 7750.88 13.26 256.77 6517.65 532.40 -3338.98 3379.85 2.59 7812.18 13.30 255.05 6577.31 528.97 -3352.64 3392.94 0.65 7873.88 13.43 254.88 6637.35 525.27 -3366.41 3406.12 0.22 7936.04 12.46 255.83 6697.92 521.75 -3379.88 3419.01 1.59 7997.93 12.31 256.46 6758.37 518.57 -3392.77 3431.38 0.32 8060.55 11.25 256.33 6819.68 515.56 -3405.19 3443.31 1.69 8123.07 11.53 256.53 6880.96 512.66 -3417.20 3454.84 0.46 8185.30 12.19 259.16 6941.86 509.98 -3429.70 3466.88 1.36 8246.50 13.38 256.77 7001.54 507.14 -3442.94 3479.64 2.13 8311.44 13.35 256.64 7064.73 503.69 -3457.55 3493.68 0.07 8373.26 13.17 254.42 7124.90 500.15 -3471.28 3506.83 0.87 8434.53 12.59 255.10 7184.63 496.56 -3484.46 3519.44 0.98 8497.19 12.00 253.45 7245.85 492.95 -3497.30 3531.70 1.11 8558.67 11.26 249.93 7306.06 489.07 -3509.07 3542.86 1.66 8619.65 10.92 247.38 7365.91 484.80 -3519.99 3553.14 0.98 8681.99 10.79 245.18 7427.13 480.08 -3530.73 3563.18 0.70 8744.58 10.43 241.63 7488.65 474.93 -3541.04 3572.73 1.19 8806.54 10.27 241.37 7549.61 469.62 -3550.82 3581.74 0.27 8868.90 9.84 240.48 7611.01 464.33 -3560.34 3590.49 0.74 8930.81 9.54 238.39 7672.04 459.04 -3569.30 3598.69 0.75 8994.58 9.80 235.37 7734.90 453.18 -3578.27 3606.82 0.90 9056.87 9.75 233.94 7796.29 447.07 -3586.89 3614.58 0.40 9119.67 9.62 230.83 7858.19 440.62 -3595.26 3622.04 0.86 9182.50 1 8.87 230.74 7920.20 434.24 -3603.08 3628.96 1.20 `9221.00 8.87 230.74 7958.24 430.48 -3607.68 3633.03 0.00 *Projected 26 CANRIG J Kalotsa 4 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drille d HRS(Ft/HR) AVE ROP CONDITION 1 9 7/8" Varel V516P2DC 4008489 5x14 114' 341' 227' 6.5 34.9 4 -6 -BT -A -X -1 -CT -BHA 2 97/8" HDBSMM65 12611378 6X13 341' 1502' 1161' 10.5 110.6 1 -1 -ER -C -X -1 -NO -TD 3 6 %" HDBS MM65D 12273689 6x10 1502' 4525' 3023' 24.6 122.9 1-2-CT-G-X-1-NO-DTF 3RR 6'/." HDBS MM65D 12273689 6x10 4525' 9221' 4696' 52.0 90.3 1 -2 -CT -G -X -1 -WT -TD 27 CANRIG Kalotsa 4 4.3 Mud Record Contractor: Baroid Date De th MW VIS (s/qt) PV YP Gels FL cc FC Sols ^/o DEW Ratio Sd ^/o MBT H CI m /I Ca m /I MD R Tvo R Spud Mud 5/14/17 120 1 120 1 8.7 1 200 32 45 32/61/65 1 11.0 1/0 1 2.8 I 0/97.0 I 0 I 33.0 I 9.9 F 750 I 80 5/15/17 416 416 8.9 120 27 40 21/54/68 10.2 2/0 4.3 0/95.5 0.75 25.0 9.1 750 40 5/16/17 1502 1395 9.15 72 24 25 10/43/58 9.8 2/06.1 0/93.6 0.25 25.0 8.6 800 40 5/17/17 1502 1395 9.15 48 21 6 1/2/2 7.8 2/0 6.1 0/93.7 0.25 20.0 6.7 800 80 5/18/17 1502 1395 9.15 46 21 1 7 1/2/2 1 7.8 2/0 6.1 0/93.7 0.25 20.0 6.6 800 80 6% KCI Pol mer 5/19/17 1502 1395 8.95 53 7 17 8/11/13 1 6.5 1 /, 1.8 0/95.4 - 0 9.8 34000 160 5/20/17 2850 2218 9.1 61 12 20 8/10/14 3.8 / 2.6 0/94.5 1.5 9.6 35000 80 5/21/17 4086 3062 9.3 55 13 19 6/12/18 3.8 Y 4.2 0/93.0 - 2.5 10.0 35000 180 5/22/17 4521 3424 9.45 50 12 18 5/9/12 4.0 / 5.4 0/91.8 3.5 10.1 35000 120 5/23/17 5215 3705 9.4 53 13 19 5/9/13 3.8 % 4.9 0/92.0 - 3.5 10.1 38000 120 5/24/17 6530 5325 9.5 59 17 20 5/10/17 3.8'/ 5.4 0/91.6 - 3.5 9.8 38000 60 5/25/17 7537 6309 9.55 61 16 18 5/9/18 3.8 / 6.2 0/90.9 4.5 10.2 37000 40 5/26/17 8290 1 7046 9.25 49 10 13 4/6/6 4.6 / 4.0 0/93.2 2.5 10.2 34000 20 5/27/17 9221 7958 9.3 50 12 16 5/6/8 4.2 '/2 4.3 0.3/92.5 - 3.0 10.0 36000 20 5/28/17 9221 7958 9.3 48 12 14 4/7/11 3.4 '/ 1 4.4 0.3/92.5 - 3.5 10.2 35000 40 5/29/17 9221 7958 9.4 50 11 17 5/9/13 3.8 / 4.9 0.1/92.0 - 3.5 10.1 37000 40 5/30/17 9221 7958 9.5 53 13 16 4/8/12 3.8 / 6.0 0.1/91.1 - 3.5 10.1 35000 40 5/31/17 9221 7958 9.52 55 13 16 4/6/11 4.0 / 6.1 0.1/91.0 - 3.5 10.3 35000 40 6/1/17 9221 7958 9.52 55 13 16 4/7/11 4.0 % 6.1 0.1/91.0 - 3.5 9.4 35000 40 6/2/17 9221 7958 9.52 56 13 17 5/10/14 4.2 '/: 6.2 0.1/91.0 - 3.5 10.1 34500 40 6/3/17 9221 7958 9.6 59 14 17 5/11/15 4.5 / 6.6 0.1/90.6 0.01 3.5 9.8 34000 40 r�uurev�aoons: FAW = [Aua Weight Gels = Gel Strength Sols = Solids pH = Acidity Vis = runnel Viscosity FL = Water or Filtrate Loss Sd = Sand content Cl = Chlorides PV = Plastic Viscosity FC = Filter Cake MBT = Methylene Blue Ca = Hardness Calcium YP = Yield Point O/W = Oil to Water ratio Alk, Pm = Alkalinity, Mud nr = Not Recorded 28 CANRIG ifJ - Kalotsa 4 4.4. Drilling Progress 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 �— 9 7/8" 6 3/4" ry0 ry1 1 ,V 1O ry0 N rl ry0 ry0 CV 1V I V C" ry0 ry0 Cv ry ,v v ry0 vO ,v ,v 29 CANRIG 5 SHOW REPORTS Kalotsa 4 CANRIG 30 CAMP,RIG llnu i ive Ten wui �u:v Lru. Hydrocarbon Show Report # 1 Operator: Hilcorp Alaska, LLC Well: Kalotsa 4 API Number 50-133-20665-00-00 Field: Ninilchik Unit Date: 5/28/2017 Rig: Saxon 169 Time: 5:28 AM County: Kenai Peninsula Borough Depth IStart jEnd State: Alaska 5350' MD 5380' MD Country: United States of America 4172' TVD 4201' TVD Averages Pixler Plot Before During After Maximum ROP (f h) 116 ft/hr 146 ft/hr 94 ft/hr 186 ft/hr 1owo WOB 6 klbs 7 klbs 6 klbs 9 klbs RPM 52 rpm 82 rpm 43 rpm 79 rpm low PP 2169 psi 2304 psi 2204 psi 2369 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/ alE ,00tAS Chloride 38,000 38,000 38,000 38,000 — Total Gas 118 728 162 1,035 'O C1 m 22,021 135,448 30,278 192,871 C2 m 19 6 - 1 2 3 4 C4 m) 39 11 C5 m 39 11 Lithology Sand ( 5340'-5370') = olive gray to brownish gray with light gray secondary hues; quartz and feldspar dominant; dominantly upper very fine to upper fine grains, with rare lower medium sized grains; moderately sorted; angular to subangular; moderate to high sphericity; unconsolidated; abundant carbonaceous material; trace dark gray, light gray, yellow, orange, brown lithics; bedded with tuffaceous sandstone; firm to firm friable; fine grained; coal beds common throughout interval; moderate outgassing observed. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a I Type n/a Amount n/a Intensity in Color n/a Color None Residual Fluorescence Intesity n/a Color n/a Amount n/a Color n/a Cut Colorjn/a Oil Show RatingFree Oil in Mud INo Comments Report by: E. Andrews CA RIG Dm, l,,i Th:CH\'()Lnf.Y r.T,,. Hydrocarbon Show Report # 2 Operator: Hilcorp Alaska, LLC Well: Kalotsa 4 API Number 50-133-20665-00-00 Field: Ninilchik Date: 5/28/2017 Rig: Saxon 169 Time: 9:28 AM County: Kenai Peninsula Borough Depth Start JEnd State: Country: Alaska United States of America 7680' MD 7725' MD 6448' TVD 6492' TVD Averages PixlerPlot +0000 Before During After Maximum ROP (fph) 126 ft/hr 127 ft/hr 44 Whir 175 Whir WOB 7 klbs 7 klbs 5 klbs 8 klbs RPM 57 rpm 55 rpm 3 rpm 55 rpm low PP 2597 psi 2521 psi 2249 psi 2505 psi Mud Weight 9.6 lbs/gal 9.6 lbs/gal 9.6 lbs/gal 9.6 lbs/ alE ,00AS Chloride 37,000 37,000 37,000 37,000 ` Total Gas 63 1,187 170 1,557 10 C1 m 13,328 252,843 36,231 252,843 C2 m 19 6 1 2 3 6 C3 m C4 m 39 11 C5 m 39 11 Lithology Sand/ Tuffaceous Sandstone (7680' - 7740') =olive gray to medium gray with very light gray hues; dominantly clear to translucent quartz and feldspar; lower very fine to upper fine grains; well to very well sorted; subrounded to round; moderate to high sphericity; unconsolidated; trace reddish orange and yellow lithics; common black to brownish black carbonaceous fragments; abundant tuff; tuffaceous sandstone; very light gray to medium dark gray; very fine to fine grained; well sorted; subrounded; moderate to high sphericity; PDC disaggregated; soft to easily friable; clay mineral cement; tuffaceous matrix; floating grain to point contact fabric; non calcareous. Cuttings Analysis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount n/a Color n/a Amount n/a Color n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Ratinq Free Oil in Mud No Comments Report by: E. Andrews CAN21G Uau.ii�r, Te�:H.oi.u,rc Lru. Hydrocarbon Show Report # 3 Operator: Hilcorp Alaska, LLC Well: Kalotsa 4 API Number 50-133-20665-00-00 Field: Ninilchik Date: 5/28/2017 Rig: Saxon 169 Time: 10:01 AM County: Kenai Peninsula BoroughDe"6745'TVD End State: Alaska7985' MD 8000' MD Countr : United States of America 6760' TVD Averages Pixler Plot IONO — Before During After Maximum ROP (f h) 117 ft/hr 122 ft/hr 149 ft/hr 129 ft/hr WOB 9 klbs 9 klbs 9 klbs 10 klbs RPM 65 rpm 61 rpm 59 rpm 57 rpm low PP 2464 psi 2432 psi 2371 psi 2309 psi Mud Weight 9.2 lbs/gal 9.2 lbs/gal 9.2 lbs/gal 9.2 lbs/gal E ,00 Chloride 34,000 34,000 34,000 34,000 Total Gas 94 347 143 501 10 C1 (ppm) 19,934 73,837 30,344 106,820 C2( m) (19 6 - Elm , x C3 m) 19 6 C4( m) (39 11 CS m 39 11 Lithology Tuffaceous Sandstone/ Sand (7970' - 8030') = very light gray to grayish white with abundant darker secondary hues; fragile and pulverulent; crunchy; irregular shaped; sparkling luster; non calcareous commonly acts as supporting matrix for loose sand grains; dominantly clear to translucent quartz and volcanic glass, trace dark liths; very fine lower to medium upper, dominantly fine upper to lower; angular to subangular; well sorted; abundant coal beds. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a Type n/a Intensity n/a Color None Amount Color n/a Amount n/a Color n/a n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud jNo Comments T83 Report by: E. Andrews CANRIG D I IFG Teon'uv.rr t:n,. Hydrocarbon Show Report # 4 Operator: Hilcorp Alaska, LLC Well: Kalotsa 4 API Number 50-133-20665-00-00 Field: Ninilchik Date: 5/28/2017 Rig: Saxon 169 Time: 10:21 AM County: Kenai Peninsula Borough Depth I Sta jEnd State: Alaska 8570' MD 8595' MD Country: United States of America 7316' TVD 7341' TVD Averages Pixler Plot Before During After Maximum ROP (fph) 120 Whir 108 Whir 90 Whir 160 Whir 10000 WOB 8 klbs 7 klbs 7 klbs 8 klbs RPM 75 rpm 75 r m 59 rpm 73 rpm 1000 PP 2166 psi 2055 psi 2371 psi 2075 psi Mud Weight 9.3 lbs/gal 9.3 lbs/gal 9.3 lbs/gal 9.3 lbs/ alAS E 100 Chloride 34,000 34,000 34,000 34,000 ' 10 Total Gas 39 679 87 1,173 C1 m 8,193 144,496 16,777 249,774 C2( m) 19 6 - 1 2 3 4 C'M cuts coca mcs C3 m) 19 6 C4 m) 39 11 CS m) 39 11 Lithology Sand/ Tuffaceous Sandstone (8580' - 8650') = medium gray to medium dark gray:. quartz and feldspar tramework. lower very fine to fine grains, occasionally lower medium to upper medium grains; poor to moderately sorted; subangular to subrounded; moderate to high sphericity; trace tuff: common black carbonaceous fragments; reddish orange, aqua, light gray, and yellow lithics; tuffaceous sandstone; light gray, moderate to strong salt and pepper appearance: friable to firm friable; fine grained; moderate to poorly sorted; subrounded; moderate sphericity; PDC disaggregated:. clay mineral cement; floating grain support; tuffaceous matrix; non calcareous; common coal beds throughout interval: weak to moderate outgassing. Cuttings Anal sis Odor n/a Fluorescence Cut Fluorescence Residual Cut Stain Amount n/a Distribution n/a Intensity n/a Color n/a I Type n/a Intensity n/a Color None Amount n/a Color n/a Amount n/a Color n/a Residual Fluorescence Cut Intesity Color n/a Color n/a n/a Oil Show Rating Free Oil in Mud INo Comments !Report by: E. Andrews DAILY REPORTS =f Kalotsa 4 r � r 31 Hilwrp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa4 /Lw {A.�,�Vt ri^� �I7 � -RIG REPORT FOR Clint Montague, Adam Dorr DATE May 15, 2017 DEPTH 479' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 112' 24 HOUR FOOTAGE 367' CASING INFORMATION 16" @ 138' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 9.875" Varel V516P2DC PDC 4008489 6x13 114' 341' 227' 6.5 4 -6 -BT -A -X -1 -CT -BHA BHA 2 9.875" HOBS MM65 PDC 12611378 6x13 341' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 374.7 @ 171 11.8 @ 280 141.4 184.46 FT/HR SURFACETORQUE 6682 @ 153 0 @ 401 4032.3 4385.59 AMPS WEIGHT ON BIT 7 @ 244 0 @ 417 2.3 0.29 KLBS ROTARY RPM 52 @ 324 29 @ 146 32.7 31.15 RPM PUMP PRESSURE 1023 @ 378 423 @ 126 814.3 1014.79 PSI DRILLING MUD REPORT DEPTH 416' MW 8.90 VIS 120 PV 27 YP 40 FL 10.2 Gels 24/54/68 CL- 750 FC 2/0 SOL 4.3 SD 0.75 OIL 0.0/95.5 MBL 25.0 pH 9.1 Ca+ 40 CCI 0.20 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0.0 TRIP GAS n/a CUTTING GAS 0 @ 0 0 @ 0 0.0 WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 0 @ 0 0 @ 0 0.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 0 @ 0 0.0 AVG 0 PROPANE (C-3) 0 @ 0 0 @ 0 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 0 @ 0 0.0 CURRENT BACKGROUND/AVG 2u PENTANE (C-5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY Pick up & racked back 50 stands of 4.5" drill pipe, 9 joints of heavy -weight drill pipe & jars; pick up PDC bit & motor, run in hole & tagged @ ACTIVITY 112; drilled to 274' & had to back ream to conductor shoe; pulled out of hole & looked at bit -bit had multiple chips on cutters; run in hole & SUMMARY clean up hale; drilled another stand down to 341'; circulate bottoms up twice & back reamed out of hole; pick up the MWD tools, sources, motor, & new bit; trip back in & drill ahead to 479'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,188.70 REPORT BY Allen Odegaard Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa4 w 1y1rT�� C N \IG REPORT FOR Clint Montague, Adam Dorr DATE May 16, 2017 DEPTH 1,502' PRESENT OPERATION Laying down BHA TIME 23:59:59 YESTERDAY 479' 24 HOUR FOOTAGE 1,023' CASING INFORMATION 16"@138' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1,466.34' 44.08" 288.54° 1,369.83' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 PDC 12611378 6x13 341' 1,502' 1,161' 10.5 1-1-ER-C-X-NO-TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 201.7 @ 1297 11.1 @ 1291 152.4 114.43 FT/HR SURFACE TORQUE 7867 @ 1474 0 @ 1484 2870.1 7025.58 AMPS WEIGHT ON BIT 9 @ 1497 0 @ 857 2.8 2.07 KLBS ROTARY RPM 82 @ 1222 0 @ 953 31.6 78.68 RPM PUMPPRESSURE 1891 @ 1497 1014 @ 479 1560.7 1784.49 PSI DRILLING MUD REPORT DEPTH 1502' MW 9.15 VIS 72 PV 24 YP 25 FL 9.8 Gels 10/43/58 CL- 800 FC 2/0 SOL 6.1 SO 0.25 OIL 0.0/93.6 MBL 25.0 pH 8.6 Ca+ 40 CCI 0.25 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 105 @ 1450 0 @ 979 14.0 TRIP GAS n/a CUTTING GAS 0 @ 1502 0 @ 1502 0.0 WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 20591 @ 1450 66 @ 622 2674.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1502 0 @ 1127 -0.2 AVG 0 PROPANE (C-3) 0 @ 1502 0 @ 1127 -0.2 CURRENT 0 BUTANE (C-4) 0 @ 1502 0 @ 1127 •0.4 CURRENT BACKGROUND/AVG 0 / 14u PENTANE (C5) 0 @ 1502 0 @ 1127 -0.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Drilling/sliding from 479' to 1,502'; pumped a 20 bbl Hi-Vis sweep; MAD passed out of hole to conductor shoe for logs; finishing laying SUMMARY down bottom hole assembly at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105.00 REPORT BY Allen Odegaard Hilcorp Alaska, LLc Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 4 ��I� REPORT FOR: Clint Montague, Adam Dorr DATE: May 17, 2017 DEPTH: 1502' PRESENT OPERATION: NIPPLE UP BOP TIME: 23:59:59 YESTERDAY: 1502' 24 HOUR FOOTAGE' CASING INFORMATION 16" @ 138' 75/8"@ 1491 41/2' @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1,466.34' 52.00° 288.54° 1,369.83' BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 12611378 6x-13 341' 1502' 1161' 10.5 1 -1 -ER -C -X -NO -TD CSG 3 6.75" DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 FT/LBS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS TOP DRIVE RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH 1502' FLOWLINE TEMPERATURE: N/A °F MW 9.15 VIS 72 PV 24 YP 25 FL 9.8 Gels 10/43/58 CL- 800 FC 2/0 SOL 6.1 SD 0.25 MBT 25 pH 8.6 Ca+ 40 OIL 0.0 / 93.6 MWD SUMMARY INTERVAL TO TOOL: GAS SUMMARY (UNITS) HIGH LOW AVERAGE UNITS DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS 0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 AVG 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/ PENTANE(C-5) 0 @ 0 0 @ 0 0 AVG 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY PRESENT PRESENT LITHOLOGY LITHOLOGY DAILY Lay down tools, R/U casing equipment for 7 5/8" Casing run, Test float equipment, RIH with 7 5/8" Casing, Run casing string to 1491', ACTIVITY land hanger, R/U cement equipment, Cement casing in place, R/D cement equipment, Install pack off, Nipple down conductor, install well SUMMARY head, Hang BOP, Nipple up DSA, Nipple up BOP while cleaning pits, Continue to Nipple up BOP at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2,105 REPORT BY Marque] Mosebay Hilcorp Alaska, LLc Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 4 CAIVRIG REPORT FOR: Clint Montague, Adam Corr DATE: May 18, 2017 DEPTH: 1502' PRESENT OPERATION: TESTING BOPE TIME: 23:59:59 YESTERDAY: 1502' 24 HOUR FOOTAGE' CASING INFORMATION 16" @ 138' 75/8'@ 1491' 41/2' @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1,466.34' 52.00° 288.54° 1,369.83' BR INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HDBS MM65 12611378 6x-13 341' 1502' 1161' 10.5 1 -1 -ER -C -X -NO -TD CSG 3 6.75" DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 FT/LBS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS TOP DRIVE RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH 1502' FLOWLINE TEMPERATURE: N/A -F MW 9.15 VIS 46 PV 21 YP 7 FL 7.8 Gels 1/2/2 CL- 800 FC 2/0 SOL 6.1 SD 0.25 MET 20 pH 6.6 Ca+ 80 OIL 0.0/93.7 MWD SUMMARY INTERVAL TO TOOL: GAS SUMMARY (UNITS) HIGH LOW AVERAGE UNITS DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS 0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 AVG 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/ PENTANE(C-5) 0 @ 0 0 CO) 0 0 AVG 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY PRESENT LITHOLOGY PRESENT LITHOLOGY DAILY Continue to nipple up BOP, install choke valve, R/U equipment on Rig for drilling while cleaning pits. Center BOP stack, Remove casing ACTIVITY bails and elevators, install drilling bails and elevators, P/U test joint and set wear busing, P/U drill pipe, rack back, and strap every 20 joints SUMMARY in derrick. Install test plug/Fill BOPE & choke manifold with water. Begin pressure testing ROPE. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2,625 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 4 WANR V REPORT FOR Clint Montague, Adam Dorr DATE May 19, 2017 DEPTH 1522' PRESENT OPERATION FIT test TIME 23:59:59 YESTERDAY 1502' 24 HOUR FOOTAGE 20' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS MM65D 12273689 6X10 1502' 20' 7:59 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 192.0 @ 1520' 114.4 @ 1502' 172.5 147.16000 FT/HR SURFACETORQUE 7025 @ 1502' 4741 @ 1512' 5181.7 4851.52686 AMPS WEIGHT ON BIT 4 @ 1509' 2 @ 1502' 3.5 3.85331 KLBS ROTARY RPM 78 @ 1502' 29 @ 1516' 34.0 30.09000 RPM PUMP PRESSURE 1784 @ 1502' 1239 @ 1511' 1368.5 1301.29004 PSI DRILLING MUD REPORT DEPTH 1522' MW 8.95 VIS 53 PV 7 YP 17 FL Gels 8/11/13 CL- 34,000 FC 1/2 SOL 1.8 SO - OIL - MBL - pH 9.8 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 224 @ 1520' 27 @ 1503' 149.5 TRIP GAS CUTTING GAS 0 @ 1522' 0 @ 1522' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 42275 @ 1520' 4600 @ 1503' 27155.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1522' 0 @ 1522' 0.0 AVG 0 PROPANE (C-3) 0 @ 1522' 0 @ 1522' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 1522' 0 @ 1522' 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 1522' 0 @ 1522' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Picked up tools, ran into hole washing and reaming, drilled out Float equipment, pumped sweep and displaced mud, FIT test. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa ��'� 4 REPORT FOR Clint Montague, Adam Dorr DATE May 20, 2017 DEPTH 2974' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 1522' 24 HOUR FOOTAGE 1452' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBS MM65D 12273689 6X10 1502' 1472' 10:03 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 218.6 @ 1925 17.1 @ 2914 157.4 80.31000 FT/HR SURFACE TORQUE 6847 @ 2938 0 @ 1669 5326.5 0.00000 AMPS WEIGHT ON BIT 10 @ 1856 0 @ 2532 4.8 6.05161 KLBS ROTARY RPM 82 @ 2171 0 @ 2346 63.5 0.00000 RPM PUMP PRESSURE 1866 @ 2505 926 @ 1524 1477.4 1599.76001 PSI DRILLING MUD REPORT DEPTH 2972' MW 9.1 VIS 61 PV 12 YP 20 FL 3.8 Gels 8/10/14 CL- 35000 FC 1/2 SOL 160 SO - OIL 0 MBL 1.5 pH 9.6 Ca+ 80 CCI .40 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 353 @ 1815' 1 @ 1525.00000 50.6 TRIP GAS 941u CUTTING GAS 0 @ 2974' 0 @ 2974.00000 0.0 WIPER GAS 1088u CHROMATOGRAPHY ppm) SURVEY METHANE (C-1) 64570 @ 1815' 341 @ 1525.00000 9365.5 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 2974' 0 @ 2974.00000 0.0 AVG 25u PROPANE (C-3) 0 @ 2974' 0 @ 2974.00000 0.0 CURRENT 46u BUTANE (C4) 0 @ 2974' 0 @ 2974.00000 0.0 CURRENT BACKGROUND/AVG 14u PENTANE (CS) 0 @ 2974' 0 @ 2974.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Tuffaceous Claystone 70%, Sand 20%, Tuffaceous Siltstone 10% DAILY ACTIVITY Drilled ahead from 1681' to 2535', pumped sweep, and circulated out of the hole to 1496' as a cleanout run. Circulated, and picked up pipe SUMMARY from 1963' to 2501'. Washed stand down from 2501' to 2535' and commenced drilling to 2794' al midnight depth. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa (v' ��'w 4 REPORT FOR Clint Montague, Adam Dorr DATE May 21, 2017 DEPTH 4092' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 2974' 24 HOUR FOOTAGE 1118' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75 HDBS MM65D 12273689 6X10 1502' 1472' 20:12 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 213.3 @ 3977' 9.6 @ 3935' 138.1 16.26000 FT/HR SURFACE TORQUE 8168 @ 4042' 0 @ 3346' 5949.9 0.00000 AMPS WEIGHT ON BIT 10 @ 3498' 0 @ 3903' 5.3 1.17056 KLBS ROTARY RPM 82 @ 3747' 1 @ 3167' 61.9 0.00000 RPM PUMP PRESSURE 2092 @ 3946' 1393 @ 3589' 1797.2 1779.31006 PSI DRILLING MUD REPORT DEPTH 4094 MW 9.3 VIS 55 PV 13 YP 19 FL 3.8 Gels 6/12/18 CL- 35000 FC 1/2 SOL 4.2 SD - OIL 0 MBL 2.5 pH 10 Ca+ 180 CCI .70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 441 @ 3580' 8 @ 3405' 75.6 TRIP GAS CUTTING GAS 0 @ 4092' 0 @ 4092' 0.0 WIPER GAS 198u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 79960 @ 3580' 1496 @ 3405' 13940.6 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 4092' 0 @ 4092' 0.0 AVG 53u PROPANE (C-3) 0 @ 4092' 0 @ 4092' 0.0 CURRENT 18u BUTANE (C-4) 0 @ 4092' 0 @ 4092' 0.0 CURRENT BACKGROUND/AVG 14u/16u PENTANE (C5) 0 @ 4092' 0 @ 4092' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Tuffaceous Claystone 80%, Tuffaceous Siltslone 10%, Sand 10% DAILY ACTIVITY Continued Drilling from 2794'to 3530', picked up, and rotated off bottom. Pumped and circulated a sweep before pulling out of hole from SUMMARY 3530'to 2754'. Continued pulling from 2754'to 2515' while back reaming. Senioed ng and then picked up 22 joints from 2501'to 3154'. Ran into hole with 6 stands from 3154'to 3530' and continued drilling ahead to 4091'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa /A AA l/w� CANRI 4 V REPORT FOR Clint Montague, Adam Dorr DATE May 22, 2017 DEPTH 4521' PRESENT OPERATION Uploading MWD Tool TIME 23:59:59 YESTERDAY 4092' 24 HOUR FOOTAGE 429' CASING INFORMATION 16" @ 138'7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4301.54' 33.76 267.04 3236.15' SURVEY DATA 4363.37' 32.85 265.00 3287.83' 4424.75' 32.29 263.82 3339.56' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.75" HDBSMM65D 12273689 6X10 1502' 4521' 3019' 24.21 MWD Failure 3 RR 6.75" HDBS MM65D 12273689 6X10 4521' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 225.3 @ 4409' 11.0 @ 4402' 135.5 187.41000 FT/HR SURFACETORQUE 9455 @ 4520' 0 @ 4401' 7419.7 8832.03809 AMPS WEIGHT ON BIT 10 @ 4302' 0 @ 4098' 7.3 5.07657 KLBS ROTARY RPM 82 @ 4227' 48 @ 4460' 70.0 79.12000 RPM PUMP PRESSURE 2478 @ 4520' 1486 @ 4399' 2027.8 2202.66992 PSI DRILLING MUD REPORT DEPTH 4521' MW 9.45 VIS 50 PV 12 YP 18 FL 4 Gels 5/19/12 CL- 35000 FC 1/2 SOL 5.4 SO - OIL - MBL 3.5 pH 10.1 Ca+ 120 CCI .90 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 578 @ 4510' 10 @ 4093' 120.9 TRIP GAS 9u CUTTING GAS 0 @ 4521' 0 @ 4521' 0.0 WIPER GAS 60u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 101035 @ 4511' 1862 @ 4093' 22215.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 4521' 0 @ 4521' 0.0 AVG 5u PROPANE (C-3) 0 @ 4521' 0 @ 4521' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 4521' 0 @ 4521' 0.0 CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) 0 @ 4521' 0 @ 4521' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Sand 70%, Tuffaceous Claystone 20%, Tuffaceous Siltstone 10% DAILY At 4091', picked up and pumped a high-viscosity sweep. Continued drilling ahead from 4901' to 4527', circulated and monitored well before pumping another sweep. Pulled out of hole from 4527' to 3830, back reamed from 3830' to 3706', circulated sweep, conditioned mud and ACTfVITY SUMMARY circulated. Continued back reaming from 3645'to 1663' and performed flow check. Conditioned mud and circulated pump sweep. Continued pulling out of hole from 1663' to 174'. Laid down MWD tool, removed sources, and downloaded data. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 4 (/^� �RI V REPORT FOR Rance Pederson, Adam Dorr DATE May 23, 2017 DEPTH 5316' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 4521' 24 HOUR FOOTAGE 795' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6.75" HDBSMM65D 12273689 6X10 4521" 795' 8:10 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 588.4 @ 4526' 1.3 @ 5141' 124.5 125.56000 FT/HR SURFACETORQUE 10452 @ 5277' 0 @ 5207' 7042.6 10107.95313 AMPS WEIGHT ON BIT 10 @ 5207' 0 @ 5074' 5.6 6.35114 KLBS ROTARY RPM 81 @ 5039' 0 @ 4954' 57.4 78.39000 RPM PUMP PRESSURE 2372 @ 5237' 1556 @ 4825' 2012.4 2181.37012 PSI DRILLING MUD REPORT DEPTH 5309' MW 9.4 VIS 53 PV 13 YP 19 FL 3.8 Gels 5/9/13 CL- 38000 FC 1/2 SOL 4.9 SO - OIL - MBL 3.5 pH 10.1 Ca. 120 CCI .70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 354 @ 5103' 10 @ 4760' 86.0 TRIP GAS 1991u CUTTING GAS 0 @ 5316' 0 @ 5316' 0.0 WIPER GAS 370u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 63522 @ 5103' 1763 @ 4760' 16050.8 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 5316' 0 @ 5316' 0.0 AVG 32u PROPANE (C-3) 0 @ 5316' 0 @ 5316' 0.0 CURRENT 132u BUTANE C-4) 0 @ 5316' 0 @ 5316' 0.0 CURRENT BACKGROUND/AVG 26u/30u PENTANE (C-5) 0 @ 5316' 0 @ 5316' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY 50% Tuffaceous Siltstone, 20% Tuffaceous Sandstone, 20% Carbonaceous shaletcoal, 10% Sand DAILY ACTIVITY Picked up MWD Tool, shallow pulse tested, loaded sources, and began running into the hole from 481'to 2680'; installing turbo every 5 SUMMARY stands. Circulated a bottoms up with 1991 units of gas, and continued running into hole from 2680'to 4480. Washed and reamed from 4480' to 4502', circulated a bottoms up and began drilling from 4521' to 5316'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 4 � Y�IV REPORT FOR Rance Pederson, Adam Dorr DATE May 24, 2017 DEPTH 6654' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 5316' 24 HOUR FOOTAGE 1338' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6.75" HDBS MM65D 12273689 6X10 4521 2133' 1943 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 215.4 @ 6164' 1.3 @ 5646' 127.8 144.61000 FT/HR SURFACETORQUE 13192 @ 6454' 0 @ 6595' 10706.6 12688.95313 AMPS WEIGHT ON BIT 9 @ 6523' 0 @ 5653' 6.5 7.89223 KLBS ROTARY RPM 80 @ 5402' 2 @ 5837' 72.7 76.01000 RPM PUMP PRESSURE 2585 @ 6222' 1721 @ 5519' 2205.1 2450.42993 PSI DRILLING MUD REPORT DEPTH 6530' MW 9.5 VIS 59 PV 17 YP 20 FL 76 Gels 5/10/.17 CL- 38000 FC 1/2 SOL 5.4 SD - OIL - MBL 3.5 pH 9.8 Ca+ 60 CCI .50 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1051 @ 5545' 24 @ 6372' 208.1 TRIP GAS CUTTING GAS 0 @ 6654' 0 @ 6654' 0.0 WIPER GAS 1128u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 175595 @ 5545' 3357 @ 6374' 37405.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 6654' 0 @ 6654' 0.0 AVG 80u PROPANE (C-3) 11 @ 5545' 9 @ 5364' 0.1 CURRENT 32u BUTANE (C-4) 0 @ 6654' 0 @ 6654' 0.0 CURRENT BACKGROUND/AVG 32u PENTANE (C-5) 0 @ 6654' 0 @ 6654' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY 60% Tuffaceous Siltstone, 30% Coal, 10% Tuffaceous Sandstone DAILY ACTIVITY Continued drilling from 5316' to 5518', pumped a high viscosity sweep, and pullout out of the hole for a viper trip from 5518'to 4466'. SUMMARY Serviced Rig, and began running back into the hole from 4466'to 5518'. Circulated bottoms up, pumped a high viscosity sweep, and continued dnlling from 5518' to 6634'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 4 /\/�� ////�� R' V REPORT FOR Rance Pederson, Adam Dor, DATE May 25, 2017 DEPTH 7583' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 6654' 24 HOUR FOOTAGE 929' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6.75" HDBSMM65D 12273689 6X10 4521' 3062' 30:04 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 201.0 @ 7489' 8.2 @ 7039' 111.2 65.01000 FT/HR SURFACE TORQUE 14661 @ 7518' 0 @ 6727' 12245.1 13673.36328 AMPS WEIGHT ON BIT 11 @ 7580' 0 @ 7051' 7.5 10.91694 KLBS ROTARY RPM 79 @ 6738' 1 @ 7538' 59.4 55.28000 RPM PUMP PRESSURE 2601 @ 7092' 1614 @ 6721' 2320.5 2289.22998 PSI DRILLING MUD REPORT DEPTH 7537' MW 9.55 VIS 61 PV 16 YP 18 FL 3.8 Gels 5/9/18 CL- 37000 FC 1/2 SOL 6.2 SO - OIL - MBL 4.5 pH 10.2 Ca+ 40 CCI 0.70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1244 @ 7505' 13 @ 6726' 125.5 TRIP GAS CUTTING GAS 0 @ 7583' 0 @ 7583' 0.0 WIPER GAS 414u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 204909 @ 7506' 2499 @ 6724' 22429.8 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 7583' 0 @ 7583' 0.0 AVG 32u PROPANE (C-3) 18 @ 7499' 9 @ 7491' 0.6 CURRENT 54u BUTANE (C-4) 0 @ 7583' 0 @ 7583' 0.0 CURRENT BACKGROUND/AVG 19u/20u PENTANE (C-5) 0 @ 7583' 0 @ 7583' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY 70% Tuffaceous Siltston, 20% Tuffaceous Sandstone, 10% Sand DAILY Drilled from 6634'to 6654', circulated bottoms up, pumped a tandem low viscosity sweep/high viscosity sweep, and began pulling out of the ACTIVITY hole for a wiper trip. Pulled out of the hold from 6654' to 5458' working through tight spots. Serviced rig, ran back into the hole from 5458'to SUMMARY 6654', washing and reaming the last stand to the bottom. Drilled from 6654' to 7102', pumped a sweep, and continued drilling from 7102' to 7580'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilichik Unit DAILY WELLSITE REPORT Kalotsa 4 [`'+ ��IV REPORT FOR Rance Pederson, Adam Dorr DATE May 26, 2017 DEPTH 8367' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 7583' 24 HOUR FOOTAGE 784' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6.75" HDBS MM65D 12273689 6X10 4521' 3846' 40:36 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 197.2 @ 8005' 6.9 @ 7639' 100.3 98.64000 FT/HR SURFACETORQUE 16782 @ 8239' 0 @ 8109' 13108.0 16048.25000 AMPS WEIGHT ON BIT 15 @ 7732' 0 @ 8112' 7.8 7.30652 KLBS ROTARY RPM 77 @ 8238' 0 @ 8102' 55.1 73.01000 RPM PUMP PRESSURE 2615 @ 7915' 1619 @ 8221' 2258.2 2029.47998 PSI DRILLING MUD REPORT DEPTH 8290' MW 9.25 VIS 49 PV 10 YP 13 FL 4.6 Gels 4/6/6 CL- 34000 FC 1/2 SOL 4.0 SO - OIL - MBL 2.5 pH 10.2 Ca. 20 CCI 0.50 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1557 @ 7710' 12 @ 8228' 137.0 TRIP GAS CUTTING GAS 0 @ 8367' 0 @ 8367' 0.0 WIPER GAS 80u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 247963 @ 7711' 2188 @ 7807' 23337.2 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 8367' 0 @ 8367' 0.0 AVG 16u PROPANE (C-3) 26 @ 7711' 9 @ 7995' 1.2 CURRENT 49u BUTANE (C-4) 0 @ 8367' 0 @ 8367' 0.0 CURRENT BACKGROUND/AVG 17u/26u PENTANE (C-5) 0 @ 8367' 0 @ 8367' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY 70% Tuffaceous Sandstone, 20% Sand, 10% Tuffaceous Siltstone DAILY ACTIVITY Drilled ahead from 7580'to 7787', picked up, pumped a high viscosity sweep, and circulated out of the hole from 7787' to 6719'. Serviced ng SUMMARY and ran back into the hole from 6719'to 7787'. Drilled ahead from 7787'to 8223', picked up and circulated new mud into the system. Continued drilling from 8223' to 8355'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa CANRIG 4 REPORT FOR Rance Pederson, Adam Dorr DATE May 27, 2017 DEPTH 9221' PRESENT OPERATION Pulling Out of Hole TIME 23:59:59 YESTERDAY 8367' 24 HOUR FOOTAGE 854' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 41/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9119.67' 9.62 230.83 7858.19' SURVEY DATA 9182.50' 8.87 230.74 7920.20' 9221.00 8.87 230.74 7958.24' BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6.75" HDBS MM65D 12273689 6X10 4521' 4700' 51:58 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 205.8 @ 9099' 5.7 @ 8969' 90.5 106.67 FT/HR SURFACETOROUE 17995 @ 9219' 14586 @ 9018' 16130.4 17031.55692 AMPS WEIGHT ON BIT 10 @ 9081' 0 @ 9219' 7.2 6.69807 KLBS ROTARY RPM 74 @ 8597' 46 @ 8596' 61.9 57.61 RPM PUMP PRESSURE 2355 @ 9113' 1665 @ 8531' 2078.9 1979.7 PSI DRILLING MUD REPORT DEPTH 9221' MW 9.3 VIS 50 PV 12 YP 16 FL 4.2 Gels 5/6/8 CL- 36000 FC 1/2 SOL 4.3 SD - OIL - MBL 3.0 pH 10 Ca- 20 CCI 0.40 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1173 @ 8579' 9 @ 9084' 97.9 TRIP GAS 0 CUTTING GAS 0 @ 9221' 0 @ 9221' 0.0 WIPER GAS 74u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 218439 @ 8579' 1251 @ 9084' 17800.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 9221' 0 @ 9221' 0.0 AVG 40u PROPANE (C-3) 11 @ 9185' 9 @ 9069' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 9221' 0 @ 9221' 0.0 CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) 0 @ 9221' 0 @ 9221' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek Formation PRESENT LITHOLOGY DAILY ACTIVITY Dulled from 8355'to 8465, pumped a high viscosity sweep, and continued drilling from 8465'to 9221' (TD). Picked up off bottom, pumped SUMMARY sweep, and circulated the hole clean. Began pulling out of the hole from 9221'to 5313'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa //^^ RIG 4 REPORT FOR Rance Pederson, Adam Dorr DATE May 28, 2017 DEPTH 9221' PRESENT OPERATION M.A.D. Pass TIME 23:59:59 YESTERDAY 9221' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3RR 6.75" HDBSMM65D 12273689 6X10 4521' 4700' 5158 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9221' MW 9.3 VIS 48 PV 12 YP 14 FL 3.4 Gels 4/7/11 CL- 35000 FC 1/2 SOL 4.4 SO - OIL 0.3/92.5 MBL - pH 10.2 Ca- 40 CCI 0.60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ (0 TRIP GAS 26u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG Su PROPANE (C-3) @ @ CURRENT 2u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2u/2u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGV DAILY ACTIVITY Continued pulling out of the hole from 5313' to 4939', reaming as needed and laying down spiral gliders. Circulate bottoms up, and back SUMMARY ream from 4939' to 4545'. M.A.D. Pass from 4545' to 2089'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3,145.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit Kalotsa 4 REPORT FOR Rance Pederson, Adam Dorr DAILY WELLSITE REPORT AY1 I w DATE May 29, 2017 DEPTH 9221' PRESENT OPERATION Clean outrun TIME 23:59:59 YESTERDAY 9221' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 3RR 6.75" HDBSMM65D DRILLING PARAMETERS RATE OF PENETRATION SURFACETORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS 50 FC 112 SOL 4.9 GAS SUMMARY (units) DITCH GAS CUTTING GAS METHANE (C-1) ETHANE (C-2) PROPANE (C-3) BUTANE (C-4) PENTANE (C-5) HYDROCARBON SHOWS 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8"@ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH INTERVAL S/N JETS IN OUT 12273689 6X10 4521' 9221' HIGH LOW @ @ @ @ @ @ @ @ DEPTH 9221' PV 11 YP 17 SO - OIL 0.1 MWD SUMMARY INTERVAL TO TOOLS HIGH LOW AVERA @ @ @ @ CHROMATOGRAPHY (ppm) @ @ @ @ @ @ FOOTAGE HOURS 4700' 51:58 AVERAGE VERTICAL DEPTH CONDITION REASON T/B/C PULLED 1-2-CT-G-X-1-Wr-TD TO CURRENTAVG FT/HR AMPS KLBS RPM PSI FL 3.8 Gels 5/9/13 CL- 37000 MBL 3.5 pH 10.1 Ca. 40 CCI 0.40 GE TRIP GAS 2384u WIPER GAS 1818u SURVEY CONNECTION GAS HIGH AVG CURRENT 536u CURRENT BACKGROUND/AVG 5u/66 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continued M.A.D. Pass from 2089'to 1540' and pulled out of the hole from 1540'to 141'. Downloaded MWD data, laid down BHA, slip SUMMARY and cut, and serviced rig. Picked up clean out BHA and ran into hole to 8602' and circulated out gas. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2705.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa4 /�/r� R /,//11�►► �� \IV REPORT FOR Rance Pederson, Robert Wall DATE May 30, 2017 DEPTH 9221' PRESENT OPERATION Prepare for BOP test TIME 23:59:59 YESTERDAY 9221' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEYDATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.50 VIS 53 PV 13 YP 16 FL 3.8 Gels 4/8/12 CL- 35,000 FC 1/2 SOL 6.0 SO - OIL 0.1 MBL 3.5 pH 10.1 Ca+ 40 CCI 0.40 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 33u CUTTING GAS @ @ WIPER GAS 1063u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (G-3) @ @ CURRENT 0 BUTANE C-4) @ @ CURRENT BACKGROUND/AVG0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Shut in well; recording shut in pressures for 30 minutes, circulated bottoms up, washed and reamed from 8661' to 9221'. Conditioned mud and SUMMARY circulated the mud weight from 9.4 to 9.5 then pumped a high viscosity sweep. Performed a flow check, pulled out of hole from 9221'to BHA, and began preparation for shell test. Performed shell test, rigged down test equipment and began preparation for BOP test. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2,105.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT ��' (G Kalotsa 4 REPORT FOR Rance Pederson, Robert Wall DATE May 31, 2017 DEPTH 9221' PRESENT OPERATION Change out logging tools TIME 23:59:59 YESTERDAY 9221' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9221' MW 9.52 VIS 55 PV 13 YP 16 FL 4.0 Gels 4/6/11 CL- 35,000 FC 1/2 SOL 6.1 SD - OIL 0.1 MBL 3.5 pH 10.3 Ca+ 40 CCI 0.70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGYlREMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Perform BOP test, rig down test equipment, and rig up E4ine. Run in hole with E -line dummy and tag 8430', pullout of hole, and rig down SUMMARY dummy run. Makeup XPT, run in hale with E -wireline, record pressures, pullout of hole, and change out logging tools.. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2,105.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa A CANRIG 4 REPORT FOR Rance Pederson, Robert Wall DATE June 01, 2017 DEPTH 9221' PRESENT OPERATION Pull out of hole with E -line. TIME 23:59:59 YESTERDAY 9221' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @138' 75/8" @ 1491' 4 1/2 @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9221' MW 9.52 VIS 55 PV 13 YP 16 FL 4.0 Gels 4!7/11 CL- 35000 FC 1/2 SOL 6.1 SO - OIL 0.1 MBL 3.5 PH 9.4 Ca+ 40 CCI 0.50 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Finished changing out logging tools, ran in hole from surface to 8430', and wireline logged from 8430' to surface. Picked up side wall coring SUMMARY tools and ran in hole from surface to 7888'. Took various side wall cores (37 Total) and began pulling out of the hole. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2,105.00 REPORT BY Eric Andrews Hiloorp Alaska, LLC Nmilchik Unit DAILY WELLSITE REPORT Kalotsa 4 CANRIG REPORT FOR Rance Pederson, Robert Wall DATE June 02, 2017 DEPTH 9221' PRESENT OPERATION Breaking down drill pipe. TIME 23:59:59 YESTERDAY 9221' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BITINFORNIATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9221' MW 9.52 VIS 56 PV 13 YP 17 FL 4.2 Gels 5/10/14 CL- 34500 FC 1/2 SOL 6.2 SO - OIL 0.1 MBL 3.5 pH 10.1 Ca+ 40 CCI 0.65 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1412u CUTTING GAS @ @ WIPER GAS 1304u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY Pulled out of the hole, laid down logging tools and wireline equipment, made up dean out BHA and began running in hole. Run in hole to TO at ACTIVITY 9221'• circulate bottoms up, pump a high viscosity sweep, and circulate out. Wash out of hole from 9221' to 8911', continue pulling out of the SUMMARY hale on elevators to 8600', pump a slug, and pull out of hole from 8600'to 7975'. Continue pulling out of hole to 5079' while laying down drill pipe. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2,105.00 REPORT BY Eric Andrews Hilcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Kalotsa 4 [v' ��I w REPORT FOR Rance Pederson, Robert Wall DATE June 3, 2017 DEPTH 9221' PRESENT OPERATION Running in with casing TIME 23:59:59 YESTERDAY 9221' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 138' 7 5/8" @ 1491' 4 1/2" @ XXXX DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9221' MW 9.6 VIS 59 PV 14 YP 17 FL 4.5 Gels 5/11/15 CL- 34000 FC 1/2 SOL 6.6 SO 0.01 OIL 0.1 MBL 3.5 pH 9.8 Ca, 40 CCI 0.45 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 25u CUTTING GAS @ @ WIPER GAS 337u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 20u PROPANE (C-3) @ @ CURRENT 38u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 17u/30u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished laying down drill pipe and prepared for running in casing. Began running production casing into hole from 127'to 7435'. CANRIG PERSONNEL ON BOARD 3 DAILY COST $2,105.00 REPORT BY Eric Andrews DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 MD 9221 TVD 7958 REQUIRED INFORMATION Operator HILCORP ALASKA LLC Completion Date 1� 8/8/2017 Completion Sttatuss 1 -GAS Mud Mud Log A-4tr `t Samples Flo \ Ld DATA INFORMATION 10 Samples 1 -j Types Electric or Other Logs Run: ROP-DGR-EWR-CTN-ALD, MSCT-GR, ADT -GR, ESC -GR, CBL-VDL- Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data ED C 28105 Digital Data Log Log Run Interval OH/ Scale Media No Start Stop CH Current Status 1 -GAS API No. 50-133-20665-00-00 UIC No Directional Survey Yes/ (data taken from Logs Portion of Master Well Data Maint) Received Comments 9/19/2017 Electronic File: Hilcorp Kalotsa 4 HH -95363 Rotary Core Data 9-11-17.xlsx 9/19/2017 Electronic File: Hillcorp Kalosta 4 HH -95363 " CEC Data - 8-16-17.xlsx 9/19/2017 Electronic File: 2698_0_1A_50X-1-7R.jpg_ 9/19/2017 Electronic File: 3368_0_2A0X-1-10R.jpg 9/19/2017 Electronic File: 3579_0_3A_50X-1-12R.jpg 9/19/2017 Electronic File: 3767_0_4A_50X-1-13R.jpg 9/19/2017 Electronic File: 3825_0_5A_50X-1-14R.jpg 9/19/2017 Electronic File: 4100_0_6A_50X-1-15R.jpg 9/19/2017 Electronic File: 4177_0_7A_50X-1-16R.jpg 9/19/2017 Electronic File: 4228_0_8A_50X-1-17R.jpg 9/19/2017 Electronic File: 4328_0_9A_50X-1-18R.jpg 9/19/2017 Electronic File: 4496_0_10A_50X-1-19R.jpg 9/19/2017 Electronic File: 4609_0_11A_50X-1-20R.jpg 9/19/2017 Electronic File: 4661_0_12A_50X-1-21 R.jpg 9/19/2017 Electronic File: 4961_0_13A_50X-1-22R.jpg 9/19/2017 Electronic File: 5101_0_14A_50X-1-23R.jpg 9/19/2017 Electronic File: 5241_0_15A_50X-1-24R.jpg 9/19/2017 Electronic File: 5267_0_16A_50X-1-25R.jpg 9/19/2017 Electronic File: 5280_0_17A_50X-1-26R.jpg AOGCC Page 1 of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 Operator HILCORP ALASKA LLC API No. 50-133-20665.00-00 MD 9221 TVD 7958 Completion Date 8/8/2017 Completion Status 1 -GAS Current Status 1 -GAS ED C 28105 Digital Data - - - - - - - UIC No ED C 28105 Digital Data 9/19/2017 Electronic File: 5362_0_18A_50X-1-27R.jpg ED C 28105 Digital Data 9/19/2017 Electronic File: 5415019A_50X-1-28R.jpg ED C 28105 Digital Data 9/19/2017 Electronic File: 6347-0-20A _50X-1-33R.jpg - - Log C 28105 Log Header Scans 9/19/2017 Electronic File: 6985_0_21A_50X-1-37R.jpg ED C 28408 Digital Data 0 0 2170630 KALOTSA 4 LOG HEADERS ED C 28408 Digital Data 10 9250 7/19/2017 Electronic Data Set, Filename: Kolatsa 4.1as ' ED C 28408 Digital Data 7/19/2017 Electronic File: Dbraw.dbf ED C 28408 Digital Data 7/19/2017 Electronic File: Dbraw.mdx ED C 28408 Digital Data 7/19/2017 Electronic File: KALOTSA4_tvd.dbf ED C 28408 Digital Data 7/19/2017 Electronic File: KALOTSA4_tvd.mdx - ED C 28408 Digital Data 7/19/2017 Electronic File: Kalotsa4.dbf. ED C 28408 Digital Data 7/19/2017 Electronic File: Kalotsa4.md.,C ED C 28408 Digital Data 7/19/2017 Electronic File: Kalotsa4_SCL.DBF , ED C 28408 Digital Data 7/19/2017 Electronic File: Kalotsa4_SCL.MDX ED C 28408 Digital Data 7/19/2017 Electronic File: kalotsa4.hdr - ED C 28408 Digital Data 7/19/2017 Electronic File: kalotsa4r.dbf ED C 28408 Digital Data 7/19/2017 Electronic File: kalotsa4r.mdx - 7/19/2017 Electronic File: Kalosta #4 05-15-2017 AM ED C 28408 Digital Data Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-16-2017 AM ED C 28408 Digital Data Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-17-2017 AM ED C 28408 Digital Data Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-18-2017 AM ED C 28408 Digital Data Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-19-2017 AM ED C 28408 Digital Data Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-20-2017 AM ED C 28408 Digital Data Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-21-2017 AM Report.pdf t AOGCC- Page 2 of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA4 MD 9221 TVD 7958 Completion Date 8/8/2017 ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data Operator HILCORP ALASKA LLC API No. 50-133-20665-00.00 Completion Status 1 -GAS Current Status 1 -GAS AOGCC Page 3 of 12 UIC No 7/19/2017 Electronic File: Kalosta #4 05-22-2017 AAA Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-23-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-24-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-25-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-26-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-27-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-28-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-29-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-30-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 05-31-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 06-01-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 06-02-2017 AM Report.pdf 7/19/2017 Electronic File: Kalosta #4 06-03-2017 AM Report.pdf 7/19/2017 Electronic File: Kalotsa 4 Final Well Report.docx 77/19/2017 Electronic File: Kalotsa 4 Final Well Report.pdf 7/19/2017 Electronic File: KALOTSA 4 - Sin Formation Log . R MD.pdf 7/19/2017 Electronic File: KALOTSA 4 - Sin Formation Log 40 TVD.pdf 7/19/2017 Electronic File: KALOTSA 4 - Drilling Dynamics. Log MD.pdf X19/2017 Electronic File: KALOTSA 4 - Drilling Dynamics i r Log TVD.pdf , Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 MD 9221 TVD 7958 Completion Date 8/8/2017 ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data Operator HILCORP ALASKA LLC API No. 50-133-20665-00-00 Completion Status 1 -GAS ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data ED C 28408 Digital Data Log C 28408 Log Header Scans 0 0 Log C 28409 Log Header Scans 0 0 AOGCC Page 4 of 12 Current Status 1 -GAS UIC No 7/19/2017 Q Electronic File: KALOTSA 4 - Formation Log • MD.pdf 7/19/2017 Electronic File: KALOTSA 4 - Formation Log Q TVD.pdf 7/19/2017 Electronic File: KALOTSA 4 - Gas Ratio Log ' P MD.pdf 7/19/2017 Electronic File: KALOTSA 4 - Gas Ratio Log ' f TVD.pdf 7/19/2017 Electronic File: KALOTSA 4 - LWD Combo Log MD.pdf 7/19/2017 Electronic File: KALOTSA 4 - LWD Combo Log P TVD.pdf 7/19/2017 Electronic File: Kalotsa 4 - Sin Formation Log , MD.tif /19/2017 Electronic File: Kalotsa 4 - 5in Formation Log TVD.tif 7/19/2017 Electronic File: Kalotsa 4 - Drilling Dynamics Log , MD.tif 7/19/2017 Electronic File: Kalotsa 4 - Drilling Dynamics Log TVD.tif 7/19/2017 Electronic File: Kalotsa 4 - Formation Log MD.tif 7/19/2017 Electronic File: Kalotsa 4 - Formation Log TVD.tif 7/19/2017 Electronic File: Kalotsa 4 - Gas Ratio Log MD.tif 7/19/2017 Electronic File: Kalotsa 4 - Gas Ratio Log TVD.tif 7/19/2017 Electronic File: Kalotsa 4 - LWD Combo Log MD.tif 7/19/2017 Electronic File: Kalotsa 4 - LWD Combo Log TVD.tif 7/19/2017 Electronic File: Kalotsa 4 Show 1.pdf 7/19/2017 Electronic File: Kalotsa 4 Show 2.pdf . 7/19/2017 Electronic File: Kalotsa 4 Show 3.pdf i 7/19/2017 Electronic File: Kalotsa 4 Show 4.pdf , 2170630 KALOTSA 4 LOG HEADERS 2170630 KALOTSA 4 LOG HEADERS Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permitto Drill 2170630 Well Name/No. KALOTSA4 MD 9221 TVD 7958 Completion Date 8/8/2017 ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28409 Digital Data ED C 28410 Digital Data ED C 28410 Digital Data ED C 28410 Digital Data Log C 28410 Log Header Scans Log C 28411 Log Header Scans ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data AOGCC Operator HILCORP ALASKA LLC API No. 50-133-20666.00.00 Completion Status 1 -GAS Current Status 1 -GAS UIC No 110 9222 7/19/2017 Electronic Data Set, Filename: Kalotsa #4 DGR_EWR_ALD_CTN.Ias 7/19/2017 Electronic File: Kalotsa 4 DGR_EW R_ALD CTN MD.cgm 7/19/2017 Electronic File: Kalotsa 4 DGR_EWR_ALD CTN - TVD.cgm 7/19/2017 Electronic File: Kalotsa 4 Definitive Survey.txt , 7/19/2017 Electronic File: Kalotsa 4 DGR_EWR_ALD CTN MD.emf 7/19/2017 Electronic File: Kalotsa 4 DGR_EWR_ALD_CTN TVD.emf 7/19/2017 Electronic File: Kalotsa 4_DGR_EWR_ALD_CTN - ? MD.pdf 7/19/2017 Electronic File: Kalotsa 4_DGR_EW R_ALD CTN P TVD.pdf 7/19/2017 Electronic File: Kalotsa 4 DGR_EWR_ALD CTN ' MD.tif 7/19/2017 Electronic File: Kalotsa 4 DGR_EWR ALD_CTN . TVD.tif 42888 42888 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa_4_MSCT_1-Jun- 2017_ConCu_R04_Sta001.1as 7/19/2017 Electronic File: Hilcorp_Kalotsa_4_MSCT_1-Jun- 2017_ConCu_R04_Sta001.dlis 7/19/2017 Electronic File: Hilcorp_Kalotsa_4_MSCT_1-Jun- 2017.Pdf 0 0 2170630 KALOTSA 4 LOG HEADERS 0 0 2170630 KALOTSA 4 LOG HEADERS 0 745 7/19/2017 Electronic Data Set, Filename: , ConCu_R01_Sta001_XPT.las 0 512 7/19/2017 Electronic Data Set, Filename: , ConC u_R01_Sta002_XPT.las 0 571 7/19/2017 Electronic Data Set, Filename: , ConC u_R01_Sta003_XPT.las 0 1053 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta004_XPT.las Page 5 of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 Operator HILCORP ALASKA LLC API No. 50-133-20665-00-00 MD 9221 TVD 7958 Completion Date 8/8/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28411 Digital Data 0 521 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta005_XPT.las ED C 28411 Digital Data 0 508 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta006_XPT.las ED C 28411 Digital Data 0 351 7/19/2017 Electronic Data Set, Filename: ConCu_RO1_Sta007_XPT.las ED C 28411 Digital Data 0 765 7/19/2017 Electronic Data Set, Filename: ConCu_R01_St3008_XPT.las ED C 28411 Digital Data 0 575 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta009_XPT.las ED C 28411 Digital Data 0 478 7/19/2017 Electronic Data Set, Filename: ConCu_RO1_Sta010_XPT.las ED C 28411 Digital Data 0 389 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta011_XPT.las ED C 28411 Digital Data 0 499 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta012_XPT.las ED C 28411 Digital Data 0 414 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta013_XPT.las ED C 28411 Digital Data 0 364 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta014_XPT.las ED C 28411 Digital Data 0 562 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta015_XPT.Ias ED C 28411 Digital Data 0 836 7/19/2017 Electronic Data Set, Filename: ConCu_RO1_Sta016_XPT.las ED C 28411 Digital Data 0 980 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta017_XPT.las ED C 28411 Digital Data 0 1574 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta018_XPT.las ED C 28411 Digital Data 0 1229 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta019_XPT.las ED C 28411 Digital Data 0 1335 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta020_XPT.las ED C 28411 Digital Data 0 521 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta021_XPT.las ED C 28411 Digital Data 0 801 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta022_XPT.las AGGCC Page 6 of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 MD 9221 TVD 7958 Completion Date 8/8/2017 ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data I ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data ED C 28411 Digital Data AOGCC Operator NILCORP ALASKA LLC API No. 50-133-20665.00-00 Completion Status 1 -GAS Current Status 1 -GAS UIC No 0 622 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta023_XPT.las 0 641 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta024_XPT.las 0 412 7/19/2017 Electronic Data Set, Filename: ConC u_R0 1_Sta025_XPT.las 0 879 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta026_XPT.las 0 701 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta027_XPT.las 0 665 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta028_XPT.las 0 506 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta029_XPT.las 0 514 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta030_XPT.las 0 456 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta031_XPT.las 0 562 7/19/2017 Electronic Data Set, Filename: ConC u_RO7_Sta032_XPT.las 0 1204 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta033_XPT.las 0 393 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta034_XPT.las 0 642 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta035_XPT.las 0 1448 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta036_XPT.las 0 697 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta037_XPT.las 0 468 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta038_XPT.las 0 777 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta039_XPT.las 0 1142 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta040_XPT.las Page 7 of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 Operator HILCORP ALASKA LLC API No. 50-133-20665-00-00 MD 9221 TVD 7958 Completion Date 8/8/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C28411 Digital Data 0 651 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta041_XPT.las ED C 28411 Digital Data 0 559 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta042_XPT.las ED C 28411 Digital Data 0 892 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta043_XPT.las ED C 28411 Digital Data 0 713 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta044_XPT.las ED C 28411 Digital Data 0 901 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta045_XPT.las ED C 28411 Digital Data 0 517 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta046_XPT.las ED C 28411 Digital Data 0 465 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta047_XPT.las ED C 28411 Digital Data 0 479 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta048_XPT.las ED C 28411 Digital Data 0 1334 7/19/2017 Electronic Data Set, Filename: ConCu_R01_Sta049_XPT.las ED C 28411 Digital Data 1476 8474 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa4_ConCu_MAfN_PASS_ADT_EC S_LDSC.las ED C 28411 Digital Data 1591 1887 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa4_ConCu_R E PEAT_PASS_ADT ECS_LDSC.las ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta001_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta002_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta003_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta004_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Stao05_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROt_Sta006_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta007_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROt_Sta008_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta009_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta010_XPT.dlis AOGCC Page 8 of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 Operator HILCORP ALASKA LLC API No. 50-133-20665-00-00 MD 9221 TVD 7958 Completion Date 8/8/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta011_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROI _Sta012_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_ta013_XPT.dlis S ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROt_Sta014_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_01_Sta015_XPT.dlis R ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROt_Sta016_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_01_Sta017_XPT.dlis R ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROI _Sta018_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta019_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta020_XPT.dlis ED C 28411 Digital Data 7/19/2017 R Electronic File: ConCu_01_Sta021_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_RO1_Sta022_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta023_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROt_Sta024_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta025_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_RO1_Sta026_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta027_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta028_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta029_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta030_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta031_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta032_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta033_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta034_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta035_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta036_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta037_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta038_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta039_XPT.dlis AOGCC Page 9 of 12 Wednesday, December b, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 Operator HILCORP ALASKA LLC API No. 50-133.20665.00-00 MD 9221 TVD 7958 Completion Date 8/8/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta040_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta041_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta042_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta043_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta044_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta045_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta046_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta047_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_R01_Sta048_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: ConCu_ROt_Sta049_XPT.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: Hilcorp_Kalotsa4_ConCu_MAIN_PASS_ADT EC . S_LDSC.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: Hilcorp_Kalotsa4_conCu_REPEAT_PASS_ADT_ ' ECS_LDSC.dlis ED C 28411 Digital Data 7/19/2017 Electronic File: P Hilcorp_Kalotsa4_ADT_01Jun17_FINAL.Pdf ED C 28411 Digital Data 7/19/2017 Electronic File: eHilcorp_Kalotsa4_ECS_01Junl7_FINAL.Pdf ED C 28411 Digital Data _ 7/19/2017 Electronic File: Hilcorp_Kalotsa4_XPT_02Junl7_FINAL.pdf ED C 28412 Digital Data -36 9130 7/19/2017 - Electronic Data Set, Filename: Hilcorp_Kalotsa4_SCMT_CBL_8July2017_ConC u_Main.las ED C 28412 Digital Data 8416 9110 7/19/2017 Electronic Data Set, Filename: Hilcorp_Kalotsa4_SCMT_CBL_8J uly2017_ConC u_Repeat.las ED C 28412 Digital Data 7/19/2017 Electronic File: Hilcorp_Kalotsa4_SCMT_CBL_8July2017_ConC - u_Mahc1lis ED C 28412 Digital Data 7/19/2017 Electronic File: Hilcorp_Kalotsa4_SCMT_C B L_8J uly2017_ConC u_Repeat.dlis AOGCC Page 10 of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 MD 9221 TVD 7958 Completion Date 8/8/2017 ED C 28412 Digital Data Log C 28412 Log Header Scans ED C 28694 Digital Data ED C 28694 Digital Data ED C 28694 Digital Data ED C 28694 Digital Data ED C 28694 Digital Data ED C 28694 Digital Data ED C 28694 Digital Data ED C 28694 Digital Data ED C 28694 Digital Data Log C 28694 Log Header Scans I ED C 28792 Digital Data ED C 28792 Digital Data I ED C 28792 Digital Data ED C 28792 Digital Data ED C 28792 Digital Data ED C 28792 Digital Data AOGCC Operator HILCORP ALASKA LLC API No. 50-133-20665-00-00 Completion Status 1 -GAS Current Status 1 -GAS UIC No 10 7/19/2017 Electronic File: Hilcorp_Kalotsa4_SCMT_CBL 08JUL17_FINAL. Pdf 0 0 2170630 KALOTSA 4 LOG HEADERS 10/17/2017 Electronic File: KALOTSA- IP 4_PERF_25AUG17.pdf ' 10/17/2017 Electronic File: KALOTSA- 4_PERF_25AUG 17_LAS.zip 10/17/2017 Electronic File: KALOTSA- 4_PERF_25AUG 17_img.tif 10/17/2017 Electronic File: KALOTSA- ALOTSA- 4—PERF — 31AUG17.pdf 4_PERF_31AUG17.pdf 10/17/2017 Electronic File: KALOTSA- 4_PERF_31 AUG 17_LAS.zip 10/17/2017 Electronic File: KALOTSA- 4_PERF_31 AUG17_img.tif 10/17/2017 Electronic File: KALOTSA-4_PRESS- P TEMP_23AUG17.pdf 10/17/2017 Electronic File: KALOTSA-4_PRESS- TE MP_23AUG 17_LAS.zip 10/17/2017 Electronic File: KALOTSA-4_PRESS- TE MP_23AUG 17_img.tif 0 0 2170630 KALOTSA 4 LOG HEADERS 9062 8822 11/13/2017 Electronic Data Set, Filename: CORRELATION.las 9064 8901 11/13/2017 Electronic Data Set, Filename: PERF 9021- , 9035.1as 9070 8929 11/13/2017 Electronic Data Set, Filename: PERF 9042- 9055.1as 9085 8863 11/13/2017 Electronic Data Set, Filename: PERF 9072- 9080.1as P 11/13/2017 Electronic File: KALOTSA 4—PERF —1 1SEPT17.pdf 11/13/2017 Electronic File: KALOTSA 4_PERF_11SEPT17_LAS.zip - Page I I of 12 Wednesday, December 6, 2017 DATA SUBMITTAL COMPLIANCE REPORT 12/6/2017 Permit to Drill 2170630 Well Name/No. KALOTSA 4 0 perator HILCORP ALASKA LLC API No. 50-133-20665-00-00 MD 9221 TVD 7958 Completion Date 8/8/2017 Completion Status 1 -GAS Current Status 1 -GAS UIC No ED C 28792 Digital Data 11/13/2017 Electronic File: KALOTSA 4_PERF_11SEPT17_img.tif ` Log C 28792 Log Header Scans 0 0 2170630 KALOTSA 4 LOG HEADERS Well Cores/Samples Information: -- -- - - - - - Interval Sample Set Name St rt Stop Sent Received Number Comments Cuttings 1500 9221 7/19/2017 1612 INFORMATION RECEIVED - - - - - Completion Report Directional /Inclination Data Ol/ Mud Logs, Image Files, Digital Dabl / NA Core Chips Y f 1 Production Test Information 16' NA Mechanical Integrity Test Information Y�N6 Composite Logs, Image, Data Files Core Photographs Y / Geologic Markers/Tops l`_/ Daily Operations Summary 'r , Cuttings Samples / Y d NA Laboratory Analyses Y / A COMPLIANCE HISTORY - - - - -- - - -- - - -`/- - - - -` Completion Date: 8/8/2017 Release Date: 5/2/2017 Description Date Comments Comments: -- - - - - - - -- Compliance Reviy: Date:-- AOGCC Page 12 of 12 Wednesday, December 6, 2017 a (C' Seth Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 ndh°°. %6A..I.LC Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 12/15/17 To: AOGCC Meredith Guhl 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 107-34 WTU I X-11 11911 K�V CD1 Kalotsa 3 21 q - l) 2 3 . Hilcorp Kalotsa3_PNX 09]UL17 71180178:09 AM File fohler T2gyZ3 CD 2 Kalotsa 4 PERF_31AUG17 17141X 172:53 PM File folder .PRESS-iEMP_23AUG17 12114rA172:53PM File folder . PERF_25AUG17 TZgco �� 12�I 14f2017 2:38 PM File folder D m m^ Please include current contact information if different from above. `��+q V+ 1n C) o G M Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 1 Date: ,=)� lS Z 01�' DATE 11/10/2017 Seth Nolan GeoTech RECEIVEL NOV 13 2017 AOGCC Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Prints and Digital data Prints: PERFORATION RECORD CDS: _J; KALOTSA 4_PERF_11SEPT17_LAS,,ip 10/19/20173:26 PM �- KALOTSA 4_PERF_11SEPT17.pdf 10/4/20173:26 PM L; KALOTSA 4_PERF_11SEPT17_img. hf 1014/2017 3:26 PM Please include current contact information if different from above. Compressed (zippe... 260 K8 Adobe Acrobat Doc... 686 K8 TIF File 1,922 KB 21 7063 28 79 2 DATA LOGGED K SENDEP Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received ey: Date: Seth Nolan GeoTech RECEIVE OCT 17 2017 OGcc DATE 10/02/2017 Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA Kalotsa 4 Prints and Digital data Prints: PERFORATION RECORD 08/25/2017 PERFORATION RECORD 08/23/2017 FLOWING BOTTOM HOLE PRESSURE SURVEY CD3: PEIZF_25AUG17 PERF_31AUG17 PRESS -TEMP 23AUG17 9/21/20171:17 PM File folder 9/21/2017 11:13 AM File folder 9/21/2017 11:15 AM File folder Please include current contact information if different from above. 21 7063 26694 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVE® SEP 2 0 2011 A_^ e% rte . o�L UUMPLETION OR RECOMPLETION REPORT AN13`O 1a. Well Status: ❑ GasO• SPLUG ❑ Other ❑ Abandoned ❑ suspended L] 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1 ' 2. Operator Name: p., Susp., or gk` Hilcorp Alaska, LLC 9'11/201T217-063 Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 14. Permit to Drill Number / Sundry: / 317-253 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 EE ded: 15, 2017 ffComp.,Su 15. API Number: 50-133-20665-00-004a. Location of Well (Governmental Section): Surface: 2281' FSL, 481' FWL, Sec 7, Ti S, R13W, SM, AK of Productive Interval: 46" FNL, 2180' FWL, Sec 12, T1S, R14W, SM, AK '- Total Depth: Z40" 2484' FNL, 2151' FWL, Sec 12, T1S, R14W, SM, AK 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 209881 • y- 2233554. Zone- 4 TPI: x- 206315 y- 2234093 Zone- 4 Total Depth: x- 206285 y- 2234071 Zone- 4 eached: 27, 2017 16. Well Name and Number: Kalotsa 4Top ons: KB: 144.5 • GL: 126.5* BF: 126.5 17. Field / Pool(s): Ninilchik Field Beluga/Tyonek Gas Pool 10. Plug Back Depth MD/TVD: 18. 9,127' MD / 7,865' TVD 11. Total Depth MVFVD: 19. - 9,221' MD / 7,958' TVD - Property Designation: (SHL) C061505 (TPH/BHL) ADL384372 DNR Approval Number: LOCI 16-004 12. SSSV Depth MD/TVD: N/A U. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes LJ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 21. N/A (ft MSL) Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 2"/5" ROP-DGR-EWR- CTN-ALD MD, 275" DGR-EWR-CTN-ALD TVD MSCT-GR, ADT -GR, ECS -GR, CBL-VDL-GR-CCL 5" FORMATION LOG MDrrVD, 2" FORMATION LOG MDIFVD, 2" LWD COMBO LOG MD1TVD 2" GAS RATIO LOG MD/TVD, 2" DRILLING DYNAMICS MD/TVD, FINAL WELL REPORT 23. CASING, LINER AND CEMENTING RECORD DEPTH MD SETTING DEPTH TVD CASING HOLE SIZE CEMENTING RECORD AMOUNT TOP BOTTOM TOP BOTTOM PULLED tGRADESETTING 16" Surface 120' Surface 120' Driven Driven 7-5/8" Surface 1,491' Surface 1,387' 9-7/8" L-226sx/T-181 sx 51 bbls 4-1/2" Surface 9,213' Surface 7,950' 6-1/8" L-675 sx/T-160 sx 24. Open to production or injection? Yes Q No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD) PACKER SET (MDrTvD) N/A "See attached schematic for details" COMPLETION d1/��.% `. DATE 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Q - Per 20 AAC 25.283 (i)(2) attach electronic and printed information ,•� VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 8/9/2017 Method of Operation (Flowing, gas lift, etc.): Flowing Test: 17 EF[ow Hours Tested: 24 Production for Test Period Oil -Bbl: 0 Gas -MCF: 850.6 Water -Bbl: 0 Choke Size: N/A Gas -Oil Ratio: N/A ubing N/A Casing Press: 208 Calculated 24 -Hour Rate 1� Oil -Bbl: 0 850.6 Gas -MCF: Water -Bbl: 0 Oil Gravity-API(corr): 1 N/A Form 10-407 Revised 5/2017 / Z / y '' Y CONTINUED ON PAGE 2 RgpMg l V SEP 2 1 2017 s�� o 9 I/ nIV F28 CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes Q No ❑ If Yes, list formations and intervals cored (MD/TVD, From/I o), and summarize Iithology 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. Core Summary to be submitted once analysis is complete. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost - Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval T146 9,021' 7,762' information, including reports, per 20 AAC 25.071. T6 5211 4040 T83 8007 6768 T90 8158 6915 T110 8467 rl T140 8745 T146 8994 T150 9177 Formation at total depth: JTyonek T150 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdlfl Bf hIICOf .COrn Authorized ,•�. •,ay ,•• ,•� ye,.T Contact Phone: 777-8389 Signature: M Date: W • Z . ZO 17 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Ninilchik Unit SCHEMATIC Kalotsa #4 11 PTD: 217-063 i M.A.. UC API: 50-133-20665-00 RKB to GL=18' 16" CASING DFTAII Size Type Wt Grade Conn.MSurf 1 1,298' 3.958" 16" Conductor — Driven to Set Depth 84 %-56 Weld 7,775' 14 7-5/8" Surf Csg 29.7 L-80 BTC 7,777' 7,785' 4-1/2" Prod Csg 12.6 L-80 DWC/CHT 9,055' 7,752 7,795 t� 7-5/8" "d 6 -3/4 - Hole yy y r. RA P 5,490 i• RA @ 6,490' RA @ 7,500' C - RA 8,496' AA a T146 4-1/2„ PBTD = 9,127'/ PBTVD = 7,865' TD = 9,221'/TVD = 7,958' JEWELRY nFTAH No. Depth ID OD Item 1 1,298' 3.958" 6.875" BakerSwell Packer v DC0CnDAT1nK¢ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T146 9,021' 9,035' 7,762' 7,775' 14 6 09/11/17 Open T146 9,037' 9,045' 7,777' 7,785' 8 6 08/31/17 Open T146 9,042' 9,055' 7,752 7,795 13 6 09/11/17 Open T146 9,056' 9,076' 7,795 7,815 20 6 08/25/17 Open T146 9,056' 9,076' 7,795 7,815 20 6 08/08/17 Open T146 9,072' 9,080' 7,811 7,819 8 6 09/11/17 Open OPEN HOLE / CEMFNT DFTAB 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/II lead and 39.5 BBLs 181sx 15.4 ( ) PPS Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4-1/2" 6-3/4" hole. 240 bbls (675sx) 12.2 Type V11 and 35.2 bbls (160 sx) 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. Est. TOC 3338' MD. C,6c, :, G t l760 `nye/+J O /1.3i7 Updated by DMA 09-12-17 n Well Name: NINU Kalotsa 4 Field: Ninilchik County/State: , Alaska i (LAT/LONG): ovation (RKB): 18 API #: 50-133-20665-00 Spud Date: 5/15/2017 Job Name: 1710633D Kalotsa 4 Drilling Contractor AFE #: AFE $ Hilcorp Energy Company Composite Report . c[i..'.i3ate,. ........ 5tttmary -.:5/11/2017 RDMO: Load ou( misc axillary loads, mud pumps, top drive HPU, Mud pits 3, 2. Prep rig floor, tie up cables, Kelley ho=:q op. Lower derrick and -`prep to remove. Continue rigging down;electrical lines and generators.;clean out water tank. Prep to remove derrick fronue loading out modulesto Kalotsa pad; Pit module 3, Generator module, skate. remove iron roughneck from rig floor, remove test pump.;LowerBOP in cradle.;Cont.RDMO; Remove derrick and load out to Kalotsa Pad. Cont with load out of mat boards, misc tools and equipment. Prep rig. Lay out felt, herculiner 5/12/2017 Pull draw works skid on sub base and load on truck. Load sub base and pony walls. Mobilize loads and derrick to Kalotsa.;Set pony walls and sub base and center over well. Set draw works skid, and derrick. Load iron roughneck on rig floor. Set Gen 1/2 module, doghouse, HPU, mud pumps, and pit modules.;Cont. to spot pit modules. R/U lights & handrails on pits. R!U shakers. C/O lines to 51/2". pump Run electrical lines, water & steam lines. 5/13/2017 Set pit windwalis, continue rigging up pits and mud pump. MPI inspect high pressure surface lines as per SLB PM program. Raise derrick, set centrifuge. Repair lights in derrick.;Sim Ops: Rig down and mobilize office trailers to Kalotsa pad, set and rig up electrical Iines.;Set wind walls on rig floor. Lay out felt, liner and set catwalk. Set gas buster and generator 3 and rig up. Set Handy -Berm containment. Prep derrick and scope. Continue to rig up electrical Iine.;Run Posen lines to office trailers. Install T -bar. Hook up TDS hydraulic lines to derrick. Unbridle blocks. Prep to pick up top drive. Rig up catwalk.;Remove top drive from shipping cradle. Install torque bushing and connect hydraulic lines and Kelly hose to top drive. Set 3rd part shacks and rig up, run Pason lines to third part shacks.;Start rigging rig floor. Install bails and elevators. Function test TDS. Install saver sub. Take on water in pits and function test centrifuge, mud pumps. 5/14/2017 Continue rigging up. Rig up floor; pipe handling equipment. Rig up centrifuge pump and electrical unit. Bring up subs and safety valves to rig floor. Organize location, misc. welding projects.;PT surface lines, test ESD. change out comm. cable on iron roughneck. Change oil in accumulator, total safety on location to rig up and test gas alarms. Function test centrifuge. Check pulsation;dampners/pop offs on mud pumps. Rig accepted at 15:OO.;install shaker screens. Build spud mud. Stage riser components by cellar area. Begin to N/U riser.;N/U riser, flow line, bleeder lines, hole fill lines. Install 12.25" wear ring. Fill riser & check for ledks.;P/U & rack back in derrick 50 #a drill pipe, 9 its HWDP & drilling jars.;Stage BHA tools & equipment. 5/15/2017 Pick up and install mouse hole. Continue staging BHA components.;Pick up BHA #1;9-7/8" PDC bit, mud motor, float sub and HWDP.;Tag up at 114', drill ahead to 276'at 350 gpm/6600 psi 30 rpms/4500 ft -lbs increasing to 420 �� gpm/780 psi 40 rpms/ 5300 ft -lbs after 1 stand. 120-200fph.;Circulate hole clean reciprocating pipe 3x annular volume. Observe pipe pulling tight while reciprocating. Attempt to back ream out of the hole, ratty torque. Stalled out twice, no movement. Work;pipe to regain rotary. Increase RPM'S to 80 with ratty torque from 71<11 -lbs to 131<11 -lbs. Smoothed out inside conductor. Pull bit to surface, significant wear/scarring on the motor; none observedpri the HWDP, appears we were dragging something up hole. Bit grade was 4-6.;Sewice rig while discussing options.;RIH with same motor/bit reaming once in open hole; 420 gpm/600 psi, 50 rpms/4500 ft -lbs. At 240' observe torque became erratic up to 8500 ft -lbs with 120 - 150 differential pressure.;Continue drilling from 276'to 344'414 gpm/600 psi with 140 diff; 53 rpms 5200 ft -lbs ROP 100-200 fph, WOB 2- SK.;Circulate 3 x annular volume and backream 1 stand, stand back HWDP/Jars. Attempt to pump out of the hole, tight at 279' (15K over). Backream out of hole 50 rpms/4500 ft -lbs 410 gpm/620 psi, one;spike in torque at 231' 8200 ft with -lbs. POOH. Bit grade 4 -6 -BT -A -X -1 -CT. Photos in O: ;M/U 9 7/8" BHA #2 to 344' (motor, MWD,LWD). Download LWD tools. Shallow hole test & load sources.;Drill ahead from 344' to 980' PU wt 40 k, SO wt 36 k, ROT 38 wt k, Trq 5/7 k It lbs, 50 rpm, 510 gpm, 1500 psi, ECD 9.32 ppg with 8.9 ppg mud.;Distance to Plan: 8.99' (.36' high / 8.50' right).;47 bbls solids to G&I, 47 bbis cum. 23 bbis class 11 fluid to G&I, 23 bbis cum 0 bbis cement to G&I, 0 bbls cum 0 bbis mud loss down hole, 0 bbls cum 5/16/2017 Cont. drill ahead from 980' to TO of 1502'sliding as needed to maintain WP O6; building up to 44° inclination. Sliding parameters: 150 - 200fph, 515 gpm/1700 psi with 230 psi diff. WOB 4-9K.;Rotating parameters: ROP 140-180fph, 520 gpm/1700 psi, SOrpms/7400 ft -lbs, WOB 5-10K. ECD's 9.6 ppg with 9.0 ppg mud.;Pump high viscosity sweep (10% excess, on time) and hole circulate clean 520 gpm/1690 psi 50 rpms/5600 ft -lbs. Circulate three annular volumes.;Back ream out of hole from 1502' to 240, MAD passing all slides to collect ALD data. MAD pass at 225 fph; 50 rpms, 520 gpm no tight spots noted.;PJSM on sources. Remove sources. Up -load LWD data. LID BHA (Bit Grade i-1-ER-C-X-I-NO-TD).;Clean & clear floor. Pull wear ring. Dummy run casing hanger.;R/U to run casing. R/U power tongs, slips & elevators. Dummy run casing hanger.;M/U 7 5/8" shoe track. Check floats (good). RIH 7 5/8" 29.7# casing to 800'.;101 bbis solids to G&I, 148 bbls cum. 219 bbis class II fluid to G&I, 242 bbis cum 0 bbis cement to G&I, 0 bbis cum 5/17/2017P e to RIH with 7-5/8" eosin from 800'to 1470' with no issues. Make up hanger and landing joint. Land casing at 1491.43 PUW SOK SOW 32K.;Make up head lines to;Breakeirculation at 3.3 bpm 155 psi; staging up to 6.5 bpm 201 psi, reciprocating pipe. Continue rigging up HES cementers and g for cement job. Just prior to pumping spacer observe hole get;sticky breaking over 25 - 30K and taking 5-10K drag. Land hanger and pick upjust off S loaded lines with 5 bills water and checked for leaks. HES pressure tested lines at 550 low 4100 high, good tests. HES pumped 31 bills 10.0 ppg pacer III at 3 bpm, 50 psi, and shut down. HES;pumped 31 bbis 10.0 ppg Clean Spacer III at 3 bpm, 50 psi, and shut down. HES dropped bottom plug ed 100 bbis 226 sx 12.0 a UII lead cement at 5 b m, 160 si, followed by 39.5 bbls;(181 sx) 15.4 Class G tail cement at 5 b m 160 si. opped top plug, then displaced with 10 bills freshwater followed by 56 bbis 9.1 Spud Mud ppg at 6bpm, 309psi. Slowed to 2.5 bpm wlth;10 bbl to go. the plug and held 1180 psi (FCP of 420 psi) for 5 minutes, bled off and floats held. Bled back 0.5 bbis to truck. Had 31 bbls Clean Spacer III return to ;and 51 bbis of 12 0 Pott le d ceme t to s rface Weli life was added to both lead and tail cement at 1/2 ppb. Mix water temp at 80 deg. Pumped 138% �✓ excesson lead and 186% tail. Did not reciprocate the;string due to overpull just prior to starting job. Had no losses. Up wt 50K, dwn wt 32K at time of landing hanger. CIP at 12:16 his, 5-17-17. RD cleaned up and released Halliburton.;Break off landing joint. Install casing packoff and test 500/5000 psi - good UD landing joint. Clean and clear rig UX floor.;N/D riser and spacer spools/DSA. Stage wellhead section and N/U wellhead. Lay over catwalk to install BOP in cellar. Stage BOP by catwalk and rig up crane.;Replace studs in DSA & replace studs in bottom of BOPE. N/U DSA & N/U BOPE. Clean mud pits.;Cont. to N/U BOPE. Install choke valve & choke & kill lines. N/U flow box. N/U flow line & gas buster. N/U koomey hoses. Build PHPA mud for production section.;108 bbls solids to G&I, 256 bbls cum. 371 bbis class II fluid to G&I, 613 bbis cum 51 bills cement to G&I, 51 bbis cum 0 tools mud loss down hole, 0 bola cum nipple, fill up line. Chain down stack and check bolts on stack. Continue building 6% KCL PHPA mud.;UD casing bails and pick up short bails. Rig ick up pipe. Rack and strep drill pipe. Install wear bushing.;Pick up and rack back drill pipe; 160 total joints of drill pipe.;Clean & clear floor. Pull wear ring. e check all connections on BOPE & re -hammer up bolts. R/U to test BOPE. Attempt to shell test. Bleed air from system.;Attempt to shell test & observe leak =nipple,flow joint & XO connecton. Break out XO and inspect threads. WU XO to test joint. Pressure up & pressure held.;Shell test 250/3500 psi (good). Test BOPE 1/2" test joint. 250/3500 psi & annular 250/2500 psi.;0 bbis solids to G&I, 256 bbis cum. class II fluid to G&I, 613 bbis cumcement to G&I, 51 bola cummud loss down hole, 0 bola cum 5/19/2017 Continue testing BOPE's 250/3500 psi, annular 250/2500 psi. AOGCC right to witness waived by Jim Regg. F/P inside kill -grease and function, inside choke work air out and function, LPR function and;work air out. Accumulator draw down: starting pressure 3025, final pressure 1300. 200 psi recharge 28 second, full recharge 117 seconds. 4N2 bottles with 2637 psi average.;Pull test plug, install wear bushing;Rig up test casing to 3500 psi - gland nut on lock down screw leaking. Bleed off tighten gland nut. Pressure up and test casing to 3500 psi for 30 minutes - a d ;Stage BHA and drill pipe. Strap drill pipe and prep to pick up BHA.;Pick up 6-3/4" BHA as per DD; MM65 bit, Motor with 1.5° bend, DM PWD. collar, Measure RFO = 1.79/4.82 = 133.7°. SP4, ALD, CTN, TM. Break out stabilizers on MWD tools. Plug in and download.;Shallow pulse test MWD. Load sources. Cont. to P/U BHA to 481'.;RIH with BHA while picking up 41/2" DP from 481'to 1300'. W&R stands out of derrick from 1300'to 1406'. Tag float cement plugs @ 1406'.;Drill out shoe trackfrom 1406'to 1502' (Float collar on depth 1408' & shoe on depth 1491').;Drill ahead 20' new hole from 1502'to 1522'.;Pump sweep & displace o ppg mu o13.5 ppg. 325 psi with 9.0 ppg mud (Pumped 4.3 bleed back 3.8 gallons, gallons).;Sowice rig. Clean out under shakers & install shaker screens.;Drill ahead from 1522' to 1881', Sliding as needed to maintain well plan. 250 gpm, 1250 psi, 60 rpm, 5-7 k Nibs trq, PU wt 40 k, SO wt 35 k, ROT wt 38 k, ECD 9.9 ppg with 9.0 ppg mud wt.;0 bbis solids to G&I, 256 bbis cum. ,�f" 100 bola class II fluid to G&I, 713 bbls cum 0 bola cement to G&I, 51 bbls cum 0 bbls mud loss down hole, 0 bbis cum 520/2017 Continue drilling ahead from 1881'to 2529' sliding as needed to maintain WP, MAD passing all slides. Sliding parameters: ROP 110 - 130 fph, WOB 5K, 285 gpm/ 1596psi with 250 diff.;Rotating parameters: 180 fph, WOB 5K, 285 gpm 1641 psi, 80 rpms 6700 ft -lbs, ECUs 10.7-10.9 ppg with 9.0 ppg MW.;Pump sweep (15% increase on time) and circulate hole clean; 4 annular volumes at 285 gpm/1400 psi; 50 rpms 5200 ft -lbs reciprocating pipe. Flow check, static.;Wiper trip to 1476'; PUW 54K SOW 38K. Observe intermittent 5-10K drag. At 1653' observe 1 bbl discrepancy in hole fill. Monitor hole, static. Continue to pull slowly observing fluid level;in stack dropping to 1476'. monitoring on trip tank. Observe slight gain in trip tank (-0.5 bbls); gas breaking out.;Trip in hole to 1963' from derrick no issues. Circulate gas out of wellbore while reciprocating pipe and rotating 50 rpms, staging to 243 1100 pumps up gpm/ psi. Max gas 971 U. Monitor hole, static.;Continue to trip in hole to 2529' with no issues.;Circulate 2 x annular volume; from 148 gpm up to 248 gpm (594 psi to 1278 psi). Max gas 1089U.;Drill ahead from 2529' to 3375', Sliding as needed to maintain well plan. 285 gpm, 1500 psi, 80 rpm, 6-8 k Nlbs trq, PU wt 56 k, SO wt 40 k, ROT wt 46 k, ECD i t ppg with 9.2 ppg mud wt.;Distance to Plan: 4.10' (.82' low/ 4.01' lett).;121 bbis solids to G&I, 377 bills cum. 344 bbis class II fluid to G&I, 1057 bbis cum 0 bbis cement to G&I, 51 bbis cum 0 bills mud loss down hole, 0 bbis cum 521/2017 Continue drilling 6J/4" hole from 3375'to 3530'sliding as needed to maintain WP. Slide parameters 85-120 fph, WOB 3-51K, 300 gpm/1844 psi with 300 psi diff.;rotating parameters: 184 fph, WOB 7-10K, 280 gpm/1941 psi 80 rpms/7300 ft -lbs ECD 11.4 ppg with 9.2 ppg mud.;Pump sweep (35% increase, on time) and circulate hole clean 278 gpm/1510 psi total of two full circulations, 50 rpms/5700 ft -lbs, reciprocating pipe. SPR's and Flow check static.;Wiper trip POOH on elevators from 3530' to 2754' with intermittent 5-10K drag. Tight spots at 3100' (20K up, 5k down wipe x1), 2854' (25K up, 10K down wipe x 3), 2788' (30K up, 5K down wipe x2).;Tight at 2754' and aftempt to wipe clean with 40K overpull not breaking over. Back ream from 2754' to 2465'; 43 rpms/6000 ft -lbs, 250 gpm/1296 psi, consistent differential pressure up to 100 to;350 psi. Attempt to pull on elevators several times but unable to.;Pump sweep at 2465' (30% increase on time) 300 gpm/l500 psi, 80 rpms/6300 ft -lbs reciprocating pipe. Significant amount of clay at shakers. POOH to 2409' with no pumps rotary no issues.;Service 3530', rig, grease crown, draw works and check oil.;RiH picking up joints of drill pipe to 3154' with consistent 5K drag. Continue running in hole to no issues no fill.;Confinue drilling 6-3/4" to 3721' hole sliding as needed to drop 2°/100 WP. Sliding 2000 as per parameters: 133fph, WOB 2-5K, 300 gpm/ psi with 200 diff;rotating parameters: 100 -180 fph, WOB 5-10K, 275 gpm/1780 psi, 80 rpms/7000 ft -lbs ECUs 11.2 with 9.25 ppg mud.;Drill ahead from 3721' to 4432', Sliding as needed to maintain well plan. 225 - 275 gpm, 1500 -180 psi, 80 rpm, 6-8 k Nlbs trq, PU wt 82 k, SO wt 46 It, ROT wt 60 k,;ECD 11.6 ppg with 9.3 ppg mud wt. Drilled thru formation @ 4365' that took a drink of fluid. Increasing back ground LCM to 30 ppb.;Distance to Plan: 7.03' (6.94' low/ 1.15' left).;57 bbis solids to G&I, 434 bills cum. 228 bbls class II fluid to G&I, 1285 bbis cum 0 bbls cement to G&I, 51 bbis cum 0 bbis mud loss down hole, 0 bbls cum 5/22/2017 Drill ahead from 4432' to 4521 % Sliding as needed to maintain well plan. ROP 150-180 fph, 274 gpm/2338 psi with 238 diff, 80 rpms/7800ft-lbs ECD 11.74 ppg with 9.4 mud.;Pump sweep (25% excess) and circulate hole clean at 287gpm/2100 psi 80rpms/8000 ft -lbs. 16 bbis lost during circulation. Pump one stand off bottom and monitor hole. Observed formation pressurizedfrom losses flowing back 22 bph quickly diminishing down to 0.2-0.5 bph in 40 minutes.;POOH on elevators to 3825'. Tight spots noted at 4308' (25K), 4171' (25K) wipe clean. Some 5-10K drag seen. At 3825' unable to wipe clean. Back ream out of hole 80 rpms/7800 ft -lbs, 276 gpm/1672 psi;to 3707'. Pump sweep and circulate hole clean. Significant amount of clay cuttings over the shaker during bottoms up. 290 gpm/1650 psi 80rpms/7600 ft-Ibs.;Continue to backream out of hole from 370T to 1663' at drilling rate 280 gpm/80 rpms. Observe consistent diff pressure and limit pulling speed based on diff pressure. flow check at 2100' - static.;Pump 11.4 ppg high vis sweep (60% increase) and hole circulate clean. 242 gpm/1050 psi 80 rpms/5835 ft -lbs. Significant amount of clay cuttings coming over shakers. Flow check- static.;Resistivity tool on LWD not working properly, discus plan forward with town & decision made to POOH for new tool.;POOH to BHA. Remove sources & download LWD data. UD resistivity tool. Cont. POOH & inspect motor & bit (good). Bit Grade: 1-2-CT-G-X-I-NO-DTF.;M/U BHA #4 to 174'. Bit motor from BHA #3 and new resistivity tool.;RIH with BHA #4 to 979'. M/U spiral glider. Cont. in hole installing spiral gliders every 5th stand to 2680'.;Fill & circ & 9.4 pipe cond mud ppg In/Out. Max gas 1992 units.;Cont. to RIH installing spiral gliders every 5th stand from 2680' to 3566'.;27 bbls solids to G&I, 461 bbls cum. 63 bbis class II fluid to G&I, 1348 bbis cum 0 bible cement to G&I, 51 bbls cum 40 bbis mud loss down hole, 40 bbls cum ue to Rim on elevators installing spiral gliders every 5th stand from 3566'to 4521'.;Circulate and condition mud staging pumps up to 300 gpM1911 psi. ate 3 annular volumes; ECD's at 300 gpm = 10.8 ppg, 256 gpm = 10.65ppg EMW with 9.45 ppg mud.;Cont directionally drilling 6 3/4" hole from 4521' to . Rotating wob 6 to 8K, 288 gpm-2047 psi, 80 rpm -9000 to 10,600 fUlbs on bolt torque, 140 fUhr ROP. Sliding wob 2 to 4K, 288 gpm-1757 psi,;155 to 240 , 50 to 80 R/hr ROP, current MW 9.4/vis58, ECD's at 10.6 ppg, BGG 16 units. Pumped a 20 bbl hi -vis sweep at 4852' while rotating, with a 20% increase Ithru ings to surface.;Cont directionally drilling 6 3/4" hole from 4972'to 5518'. 280 gpm, 1800 psi, WOB 10 k, Drilling torque 10 - 11 k R/Ibs, 80 rpm, PU wt 126 wt 54 k, ROT wt 74k.;Pumping sweeps every -300' or as ECD's increase to in hole aid cleaning. ECD's 11.0 - 11.1 ppg with 9.4 ppg mud wt. Average 30% se in cutting with sweeps and .3 ppg decrease in ECD's.;Distance to Plan: 1.19' (.62' Low / 1.02' Left).;Pump sweep & circ hole clean for wiper trip with 280 1800 psi, 45 rpm, (30 % increase in cuttings with sweep).; POOH wiper trip from 5518' to 4466' Few tight spots with 30 k over pull. Work thru once then pull ee.;54 bbls solids to G&I, 515 bbis cum. 126 bbis class II fluid to G&I, 1474 bbis cum 0 bbis cement to G&I, 51 bbis cum 0 bbis mud loss down hole, 40 bbis cum 5/24/2017 Service rig and topdrive with bit parked at 4466'.;TIH on elevators from 4466' to 5493' (dwn wt 52K) with no issues. MU topdrive on last stand, fill pipe and wash to bottom at 5518'.;CBU one time at 201 gpm-1129 psi, 50 rpm -10,400 fUlbs off bott torque, to warm up mud. Had a max of 1131 units at bottoms up. Made connection and pumped 20 bbl hi -vis nutplug sweep.;Resumed drilling 6 3/4" hole from 5518' to 6149'. Rotating wob 7-8K, 284 gpm-2262 psi, 80 rpm -11,100 It/lbs on bolt torque, 130 fUhr ROP, MW 9.3+/vis 62, BGG 55 units. Slid total 15' all day.;Pumped a second sweep at 5850' with a 25% increase in cuttings. ECD's have been slowly climbing throughout the day from 10.6 to 11.6 ppg.;With stand drilled down at 6149', pumped a third 20 bbl hi -vis nutplug sweep around at 286 gpm-2089 psi, 60 rpm -10,300 ft/lbs off bott torque, BGG 43 units. Had 10% increase in cuttings. Checked;pressure scale (mud balance) for calibration, found to be off 1/10th, reading light. Calibrated and have 9.5 ppg mud in active, thus the higher ECD reading. Had rig visit by HSE Rep Matt Hogge.;Cont directionally drilling 6 3/4" hole from 61 49'to 6654'. 265 gpm, 1950 psi, WOB 10 k, Drilling torque 13 - 15 k ft/Ibs, 80 rpm, PU wt 150 k, SO wt 62 k, ROT wt 82k.;ECD 11.4 ppg with 9.5 ppg mud wt, pumping sweeps as needed to aid in hole cleaning ;Pump tandem sweep & circ hole clean for wiper trip, 280 gpm, 2150 psi, 50 rpm, i i - 12 k Mbs trq. 20% increase in cuttings. Shakers continued to have significant amount of cuttings after 2 B/U.;Pumped a second sweep high vis & cont. to circ clean. 10% increase in cuttings and shakers cleaned up.;POOH wiper trip from 6654' to 5458'. Various tight spots work thru several times & pull thru free. Tight spots correlated with tuffaceous sandstone formations.;Sewice rig. Grease blocks, crown, top drive, draw works & iron roughneck. Clean mud pump suction screens.;RIH from 5458'to 6654'. Wash & ream last stand to bottom. (no issues running in hole).;Distance to Plan: 3.54' (2.12' Low / 2.83' Right).; 108 bbis solids to G&I, 623 blots cum. 252 bbls class If fluid to G&I, 1726 bbis cum 0 bbis cement to G&I, 51 bbis cum 0 bbls mud loss down hole, 40 bbis cum illing 6 3/4" hole from 6654'to 7195'. Rotating wob 6-8K, 272 gpm-2196 psi, 80 rpm -13,590 fUlbs on bott torque, 105 ft/hr ROP. Sliding wob 2K, 264 gpm- si, 225 psi;diff, 30 R/hr ROP. MW 9.5/vis 58, ECD's at 11.1 ppg, BGG 43 units. Pumped a 20 bbl sweep at 7062' with a mere 10% increase in cuttings to . MI Rep came out and serviced centrifuge.;Cont drilling 6 3/4" hole from 7195' to 7787'. 260 gpm, 2000 psi, WOB 5-10 k, Drilling torque 14 -16 k f llbs, Isurface. , PU wt 180 k, SO wt 70 k, ROT wt 100 k.;Pumping sweeps to aid in hole cleaning. ECD's 11.0 - 11.1 ppg with 9.50 ppg mud wt. Average 10 - 20% e in cultings.;Distance to Plan: 12.53'(1.62'Law/ 12.42'Right).;78 bbls solidsto G&I, 701 bbis cum. ls class II fluid to G&I, 1993 bbis cum ement to G&I, 51 bbis cum ud loss down hole, 40 bbis cum 5/26/2017 Pumped a 20 bbl to -vis to -wt sweep at 7787' (wiper depth). 267 gpm-1939 psi, 80 rpm -14,500 fl/lbs off bott torque, MW 9.51vis 65, ECD's at 10.9 ppg, Did two full cires.;Had 10% increase in cuttings to surface. Shut down and flow check, slight loss over 10 minutes.;Pulled wiper trip on elevators from 7787'to 6654' with no issues. Had two 10K over pulls, did not have to work on elevators. Up wt 200K, talc hole fill = 6.8 bbls, actual hole fill = 10.4 bbls.;Serviced rig and topdrive, also changed air boot on suction line from pits to pump skid.;TIH on elevators from 6654' to 7724' with no issues. MU topdrive, filled pipe and washed last stand to bottom at 7787' ;Made connection and started 20 bbl hi -vis nutplug sweep while drilling ahead. Had max of 1400 units gas at bottoms up. Rotating wob 8-10K, 260 gpm-2231 psi, 80 ft/hr ROP. Sliding wob 3K, 265 gpm-2026;psi, 200 psi diff, 26 R/hr ROP. MW 9.51vis 64, ECD's at 10.8, BGG 27 units. Drilled from 7787' to staging 8223'. Pulled 200 bbls mud from active and replaced with 200 bbls new mud.;PU off bottom and reduce pump rate to idle, to allow new mud to shear, slowly pump rate up as fluid allowed, changed shaker screens to keep mud on shakers.;Added 265 bbls ECD's.;Cont new mud to system to help reduce solids, rheology, and drilling 6 3/4" hole from 8223' to 8719', 260 gpm, 1700 psi, WOB 5-10 k, Drilling torque 14 -16 k ft/lbs, 80 rpm, PU wt 200 k, SO wt 82 k, ROT wt 120 k.;Pumping sweeps to aid in hole cleaning. ECD's 10.3 -10.5 ppg with 9.30 ppg mud wt, Average 10% increase in cuttings. Adding NXS lube to reduce torque.;Distance to Plan: 4.71' (0.45' High / 4.69' Right).;78 bbls solids to G&I, 788 bbls cum. 473 bbis class II fluid to G&I, 2446 bbls cum 0 bbls cement to G&I, 51 bbis cum 0 bbis mud loss down hole, 40 bbls cum <n 5/27Y2017 C t drillin 6 3/4" hole from 8719' to TD at 9221' and 7958' Nd. Rotating wob 6 to 8K, 269 gpm-2053 psi, 65 rpm -16,000 to 17,000 ft/Ibs on bolt torque, 20 to 150 fbhr ROP, MW 9.3Nis 56,;ECD's at 10.4 ppg, ung s. Did not attempt to do any sliding. TD'd 13' low and 44' left of the line in tuffaceous sand, ash, claystone and sand.;Had to stop rotary on upstroke when working pipe due to high torque. Pumped a 20 bbl hi -vis nutplug sweep.;Circulated just over two full circulations. 268 gpm-1881 psi, 70 rpm -16,000 to 17,000 ft/Ibs off bolt torque on down stroke, no rotation on up stroke. Had 10% increase in cuttings to surface.;Flow check (static) POOH on elevators from 9221' to 4939', reamed thru various tight spots that correlated with coal and sandstone seams.;Hole tight @ 4939'& not able to work thru on elevators. Max over pull 40k (LID spiral gliders);Circ & cond mud with 1 B/U, 243 gpm, 1400 psi;BROOH from 4939' to 4545'.;Cont. to BROOH MADD passing from 4545' to 4200' (UD spiral glidem);81 bbis solids to G&I, 869 bbls cum. 369 bbis class II fluid to G&I, 2835 bbis cum 0 bbis cement to G&I, 51 bbls cum 0 bbis mud loss down hole, 40 bbis cum 5/28/2017 Cont to pull up hole from 4200' to 274T at 180 ft/hr, making mad pass to surface shoe (1491'). 266 gpm-1272 psi, 60 rpm -6200 fulbs off bolt torque,;MW 9.3/vis 46, ECD's 10.0, BGG 2 units. Received SLB a -line equipment trailer and off loaded same.;Cont to pull up hole from 2747to 1540' MADD passing with 252 gpm, 1093 psi, 50 rpm, 4 - 6 k ft/lbs trq. MW In/Out 9.3 ppg.;F/C (static) POOH on elevators from 1540' to 481'.;17 bbls solids to G&I, 886 bbls cum. 68 bbis class II fluid to G&I, 2903 bbis cum 0 bbis cement to G&I, 51 bbls cum 0 bbis mud loss down hole, 40 bbis cum 5/29/2017 Cont POOH, rock back HWDP and NM DC's, remove RA sources, plug in and download MWD data, LD all directional BHA. Bit graded at 1 -2 -CT -G -X -I -WT -TD. Clean floor.;Cut and slip 139' drill line, service rig and topdrive.;MU BHA 95 (cleanout assembly), re -run HDBS PDC, bit sub, IBS stab, NM DC's, XO, HWDP, jars, HWDP. Cont TIH on drill pipe filling pipe every 20 stands.;Stopped at 2829', filled pipe and CBU one time, 260 gpm-539 psi, 50 rpm -5600 ft/Ibs off bolt torque. Had a max of 20 units at bottoms up.;Cont TIH filling every 20 stands, from 2829' to 6106'.;Stopped at 6106', filled pipe and CBU one time, 260 gpm-845 psi, 50 rpm -9000 to 12,500 ft/lbs off bottom torque_Had a max of 1820 units at bottoms o.;Cont TIH filling every 20 stands, from 6106' to 7654' reaming various tight spots.;W&R from 7654'to 8661' due to tight hole. Background gas starting to increase @ 8661'. Decision made to circulate out gas and condition mud prior to continuing into open hole.;Circ & cond mud. Observed a max gas of 2384 units and gas trends were trending down. w/ 1100 units observed on Pason, had drilling mud come over rotary table, flow show increased from 20% to 50%;with a 4 bbl pit gain. Hole un -loading cuttings and losing some fluid over end of shakem.;Driller and tour pusher spaced out in BOPE @ 6929'& shut in well. Monitored SICP and SIDPP. SICP initial 84 psi with 212 psi max. Pressure leveled out after 30 min / SIDPP 0).;Decision made to circ out gas thru choke. Lined up and circulated one full circ through choke and poor boy degasser vessel to circ out gas with 48 spm, drill pipe pressure 559 psi & casing pressure O.;After one full B/U at slow pump rate, checked for flow and Flow check was static.;Circulate 1 more bottoms up at full drilling rate with 248 gpm, 1128 psi & max gas 928 units. Flow check was static.;Continue to wash & ream into open hole to TD of 9221'.;Pump sweep & circ hole clean & increase mud weight to 9.5 ppg. Max gas 1063 units. Circulated 2 full circulations.;F/C (static) POOH on elevators from 9221'to 9088'.;l 7 bbis solids to G&1,903 bbis cum. 68 bbis class 11 fluid to G&I, 2971 bbis cum 0 bbls cement to G&I, 51 bbis cum 0 bbis mud loss down hole, 40 bbis cum 5/30/2017 Cont POOH on elevators from 9221', up wt 240K. Flow checked at 8599, 7032', 5076' and 1500'. Fluid dropping in wellbore. Hole took 14.5 bbis over calculated for entire trip. MW 9.5 ppg.;Cleared and cleaned rig floor. Hole taking 1/2 bph on trip tank. Drained BOP stack, pulled wear ring, installed test plug and joint, RU 1" hose to f11 hole via upper annulus valve.;Flooded stack and surface lines. AOGCC Rep Lou Laubenstein on location, Total Safety Rep on location. Loaded and shipped out Sperry tools. Attempt shell test. Chart recorder issues.;CO clock on chart recorder, Rig up chart recorder. Fill stack.;She11 test BOPE. 4.5" testjoint installed. 250 psi low, 3500 psi high. Good. AOGCC Inspector Lou Laubenstein on the rig floor. Begin test. 250 psi low for 5 mins. 3500 psi high for 10 mins.;on all components 2500 psi high on annular preventer. i fail/pass, HCR choke side, serviced and passed. Total Gas on location and tested all gas alarms and strobe lights with AOGCC inspector.;Accumulator test. Initial pressure 3150 psi. After closure 1450 psi. 200 psi build back in 20 secs. Full pressure attained 90 sees.4 nitrogen bottles @ 2750 psi. Draw down tests on both chokes.;Rig down test equipment. Pull test plug. Install wear bushing. Wellbore taking .5 BPH during test. Rig down fill up line in cellar, lineup to trip tank.;Spot in logging truck. Prejob with SLB crew and rig crew. Rig up E -Line. Monitor well on trip tank.;1st run: Gauge run to bottom. Had some minor resistance from 1850 down to 2500'. Hole appears in good shape. Tag up @ 8430' MD. 15 foot coal bed. Unable to get below. POOH for the RFT tool.;9 bbis solids to G&1,912 bbis cum. 81 bbis class II fluid to G&I, 3052 bbl, cum 0 bbls cement to G&I, 51 bbis cum 30 bbis mud loss down hole, 110 bbls cum POOH with 5.5" drift on a -line, from 8430'to surface and LD tool string. At 843U we have a fairly large coal seam. No issues pulling back up hole.;C/O tool string to RFT/ECS assembly. Surface test ok. RIH on a -line to 7888'and set down numerous times on a small coal seam. Notify Reservoir Engineer. No issues pulling up hole.;Obtain RFT's starting at 6401', up to 3890'at a total of 22 stations. Crew pulled and rebuilt trip tank pump. Fluid loss to well last 12 hrs = 7.4 [5131/2017 bbls.;Electric line logging. RFT data collection. 46 stations completed. Highest calculated pressure measured @ 5658' MD. 9.37 ppg EMW. Final station was 1656' MD. POOH to pick up ADT tools. Lost 3.6 bbls.;SIMOPS: Finish installing rebuilt trip tank pump. Flush scale out of poorboy degasser. Go through mud S pump #1. Change out valves, 1 on discharge, 2 on suction side.;Lay down RFT assembly. Pick up ADVECS assembly. RIH. Begin logging @ 8430'MD. Sat � down on same 15'coal bed. Begin logging. Log up to 5825'MD. 730'/hr logging speed. Wellbore drinking .5 BPH.;0 bbis solids to G&1,912 bbls cum. 0 0 bbis class II fluid to G&I, 3052 bbis cum 0 bbis cement to G&I, 51 bbis cum 19 bbls mud loss down hole, 129 bbis cum 6/1/2017 Cont to log open hole on a -line with ADT/ECS assembly, from 5825' up to 1491', POOH and LD a -line assembly. MI Rep on location to check measurements for replacement centrifuge.;MU sidewall core assembly (55' long), RIH on a -line to 7075' checking up weight every 1000'. Rig crew performing PM's on mud pump motors and brake inspection. Hole taking just over 112 bph.;RIH to 7888' MD. Unable to get deeper. Correlate and get on depth. POOH to 7075'. Begin sidewall core at this depth as per Geologist. 48 cores attempted. SIMOPS: Clean/Flush out centrltuge.;Change out oil in MP#1 engine. Wellbore taking .76 BPH. Complete casing checklist. Rig crew completed PM's for Tool Pusher.;POOH with core assembly. Lay down tools. Collected 37 cores of 48 attempts. 77% recovery. Rig down SLB logging unit and release the crew.;Service rig. Prepare to trip in the hole.;Trouble shoot starter on rig floor motor. Switch out starters. Change out batteries. Recharge batteries. Monitor well on trip tank.;Pick up assembly #6. Clean out assembly. 6.75" Rerun HDBS MM65D PDC bit, bit sub w/ Float, IBS stab 6.5", 2- 4.75" flex wllars, jars, 11 HWDP. TIH to shoe @ 1491' MD.;Break circulation. 140 GPM, 30 RPM, CBU.;4 bbis solids to G&1,916 bbis cum. 86 bbis class 11 fluid to G&I, 3138 bbis cum 0 bbls cement to G&I, 51 bbis cum 15 bbis mud loss down hole, 144 bbls cum i 6/2/2017 CBU at 1490', TIH from 1490'to 2857', filled and CBU with 57 units. TIH to 4538', filled and circulated one round with a max of 188 units. TIH to 5318', filled and circulated one round with a max of;233 units. TIH to 6567', filled and circulated one round with a max of 569 units. TIH to 7816', filed and circulated one round with a max of 1413 units. TIH to 9159' and MU topdrive. Washed last;stand down to 9221' with 10' of fill. Saw nothing at 7888' where a -line set down on runs #2 and #4. Saw just a slight bobble at 8430' where a -line set down on runs #1 and #3. Entire trip on elevators.;We were also 7 blots under on pipe displacement for entire trip. Received tree for well.;Pumped a 20 bbl hi -vis nutplug sweep around. Hole unloaded coal at bottoms up. Dime sized and smaller chips. Started seeing nut plug 400 strokes late, saw hi -vis mud 800 strokes late.;Pumped at 260 gpm-1054 psi, 55 rpm rot torque = 18,000 ft/lbs, up stroke = 17,000 ft/lbs, down stroke = 15,000 ftAbs. Had a max of 1305 units gas at bottoms up. Did second circ unfit shakers clean.;Had a 50% increase in cuttings at bottoms up, maybe 20% with sweep to surface (much finer coal/sand). Obtained SPR's and flow check.;Serviced rig and topdrive while observing well for flow (no flow).;Pump out 5 stands. 130 GPM, 460 PP. Wiped one section 9060 to 9040' MD, second time, it was clean. Line up on TT. Pull 5. Good hole fill. Monitor well. Dropped 2" in 10 mins. Pump dryjob.;Gained 2 bbis from dry job ( Expected pit gain). Mud level dropped 140+ feet. (145' calculated).;Begin laying down singles, from 7975' to 5079' MD. Hole fill Calculated=23 bbis, Actual=26.5 bbis.;Continue to lay down singles to the casing shoe.149V MD. Monitor well. Static. 10 bbls over calculated fill.;Lay down singles to the top of the HWDP. 14 bbis over calculated hole fill. Flow check. Empty trip tank. Swap elevators around to come out of derrick.;Trip in the hole with the remaining 20 stands in the derrick to the shoe, and two stands past.;Lay down 4 joints. Back inside casing. CBU. Monitor well. Pump 12 bbl dry job. Lay down singles. 800' MD at report time.;0 bbls solids to G&1,916 bbls cum. 0 bola class II fluid to G&I, 3138 bbis cum 0 bbls cement to G&I, 51 bbis cum 18 bbls mud loss down hole, 162 bbis cum 6/3/2017 Cont POOH LD 4 1/2" DP, HWDP and cleanout BHA. No change in bit grade (1-2).;Clean and clear rig floor, pull wear ring, dummy run hanger/landing jnt, CO to long bails, RU casing tongs and air slips, stage centralizem.;Held PJSM with rig crew and Weatherford casing crew.;PU and MU shoe track, filled and checked float equipment (OK), cont PU RIH w'th 4 1/2" DW 126# L-80 casino Filling on the fly, top filling every 10jnts. Stopped and CBU at 1490', 3009', 4515',;6050' (Max gas 109 units) and 7435' MD (Max gas 337 units). Pump with 230 GPM (5.5 BPM), (Cementers on location 21:00 hrs). Rigged up by 23:00 hrs).;Run f casing from 7435 to 8963'. Set 10k down. Pick up no over pull. Make up circulating swedgeffop drive.;Stage pump up to 250 GPM, 800 PP, 130k up , 55k down. Set down to 30k, and allow pump pressure to climb, washing obstruction `1`� away. Make 8 feet of progress to 8971. Setting 25 to 30k down.;Continue to make slow progress from 8971'to 8975' MD. No overpull, Setting down to 30k, and washing rubble away. Small coal chips seen on shakers. Max 156 units. Made � gas it through.;One last downward pop, and the shoe broke free. (Small coal seen @ 8950' and 8970'.) Ran casing from 8975' to 9215. Picked up one extra jointto wash to 9215. CBU.;9 bbis solids to G&1,925 bbls cum. 91 bbis class II fluid to G&I, 3229 bbls cum 0 bbls cement to G&I, 51 bbls cum 25 bbis mud loss down hole, 187 bbis cum 6/4/2017 CBU and reciprocate casing at 261 gpm-689 psi. Max of 42 units gas at bottoms up. Working pipe down to 9215' (shoe depth will be 9212'), no issues working pipe at all, up wt 140K, dwn wt 56K.;Down pump, LD working jnt, MU landing jnVhanger and land same. MU headpin and resume circ with hanger off seat while RD Weatherford equipment. Stage Halliburton cement equipment on rig floor.;Down pump and removed head pin. Loaded plugs and MU plug launcher on landing Int. MU hardlines and cement manifold. Resumed circulating.;Held PJSM with rig team, Peak drivers and Halliburton cementem.;Lined up on pump unit and started to circ 5 bbls water. Bad leak on valve manifold on plug launcher. Removed valve cluster and swapped end for end, then re -installed (ports not evenly spaced).;Halliburton pressure tested lines at 800 low 4000 high, good tests.;Halliburton pumped 36 bbis 12 ppg Clean Spacer III at 4 bpm 445 psi and shut down. Halliburton dro ed bottom lu and Pumped 240 bbis 675 sx 12.2 T e I-II lead cement at 5.5 b 17 15.3 of p Class G Tail cement at 4 6 m, 160 s1. Halliburton dropped top plug, then displaced with 10 bbls freshwater, followed by 138.75 bbis 6% KCL at 7 bpm,;2655 psi. Slowed to 3 bpm with 10 bbls to go. Started seeing high PH in returns 98 bbls into displacement, started overboard returns 100 bbis into displacement. We did not bump the plug (talc = 138.S;actual = 139.75 bbis) but held 2041 psi (FCP 2156 at 3 bpm) for 3 minutes, bled off and floats held. Bled back 1 bbl to truck. Had 11.9 ppg spacer returns with 12.9 ph at shutdown, and a trace of;cement. WellLlfe 1094 was added at 1/2 ppb, to both lead and tail. Mix water temp = 70 deg. Pumped 35% excess on both lead and tail. Did not reciprocate the string due tight tolerance of hanger;in BOP stack. Held hanger 2' off seat throughout the iob. Had full returns thro ohout the iob Up wt 148K, dwn wt 60K prior to landing hanger. CIP at 12:07 6-4-17.;Due to pm, spacer with trace of cement to surface, drained BOP stack into cellar box. Halliburton Flushed pump unit into cuttings box.;Filled and flushed stack 3 times with black water. Vac'd out cellar box while removing Halliburton equipment from rig floor. Backed off landing jnt and pulled to floor. Start pulling mud from pits.;MU "Cactus" brand packoff assembly and landed same. Verified and RILD's. Tested packoff at 500 psi f/5 minutes, then at 5000 psi for 5 minutes. Good tests. LD landing joint.;Halliburton lab results specify 17 hrs 45 minutes to achieve 500 psi compressive strength on lead, 11 hrs 44 minutes on tail. Cont pulling mud from pits, shipping to G&I, remove long bails, spray;denick down with detergent for cleaning, remove skate from catwalk for inspection and repair (cracks and Teflon). Caring mudloggers RD and released.;Waiting on 500 psi compressive strength to be attained (0600 firs). SIMOPS: Clean catwalk skate. Remove bucket and take to welder off location for repair, pressure wash derrick, clean mud;tanks, haul off mud and rinsate, disconnect and lay down gas buster, open and inspect same, clean out scale from inside gas buster with pressure washer and Peak Vac truck.;WOC. SIMOPS: Continue to clean and empty the mud pits. haul off mud from the pits. Continue to service and clean scale from poor boy degasser. Pressure wash derrick. Rig down steam Iines.;Clean rig floor, Draw works, sun deck, stack and cellar, re -install covers on poor boy, clean out and rig down mud pumps discharge and suction lines, stage tools for nipple down.;Fill stack with water, bleed air out of test pump lines, kill line, blind ram cavity in preparation of casing test.;Rig to test up casing. Close blinds line up to pump in the kill line with the test pump. Set up chart recorder. (Theoretical 500 psi reached by report time. );34 bbls solids to G&1,959 bbis cum. 1117 bbis class II fluid to G&I, 4346 bbis cum 0 bbis cement to G&I, 51 bbls cum 20 bbls mud loss down hole, 207 bbis cum 1/2" casin at 3500 si for 30 minutes on chart. Pumped 73.75 gallons and bled back 73.75 gallons. Good test. RD test equipment. Wellhead Rep on n, installed BPV.;ND flow line, riser and drip pan. RD choke and kill lines. ND BOP stack hang and off on trolley's at cellar entrance. Mud Engineers RD leased at 10:OO.;NU tubing head adaptor and Bowen cap, test neck seals at 500 psi 1/5 min, 5000 psi f/5 min (good), tested void at 500 psi f/5 min, 5000 F min (good). Left 4" BPV in hanger, returned 11" equtp.;RD topdrive and cradle same, scope down mast and LD lower torque tube section. Moved cement upright water tank. Shipped Weatherford casing M�t equipment. Pason Rep spooled up hard wired alarms on;pits and cellar. MI Rep and rig electrician ed long power cord from used control panel to new panel. Cont RD pits and pump skids for move. Spotted crane and removed windwalis from rig floor aker dumps. Crane removed hooch from centrifuge stand, then removed centrifuge for return for servicing. LD beaver slide. Crane picked BOP stack from and set in BOP cradle.;RIG RELEASED at 18:00 hrs on 6-5-17.;Prepare to lay down derrick, hang off blocks, unspool drill line, remove winch line rollers, e up drill line, tie up Kelly hose, dis-assemble brake linkage, remove double ball valve clamp,;remove ent iC[O.< nn 1.., -- wash pipe, clean out bulk water tank and all fluids n Well Name: NINU Kalotsa 4 Field: Ninilchik County/State: , Alaska (LAT/LONG): avation (RKB): API#: 50-133-20665-00 Hilcorp Energy Company Composite Report Spud Date: Job Name: 1710633C Kalotsa 4 Completion Contractor AFE #: AFE $: fk i 1 10 Apthilly Date '. ,.:. Ops Summary...... ;.. 7/8/2017 PTW and JSA. Spot equipment and MU 3-1/2" Junk Basket.,RIH w/3-1/2" JB and tag at 9068' KB. The tag was not correlated. SLB didn't have the ray game to run with JB. POOH. No problems.,MU and RIH with CBL, correlate to OHL and tag at 9075' Logged to 35'. Swing over to Kalotsa #3 . to run CBL. Send log to town. 7/22/2017 Obtain PTW. Hold safety meeting. Discuss job procedure with crew. Fire equipment.,Pick inj head. stab 10' lubricator. Make up reverse out -`BHA OD 5.6' long. Stab Pt ROPE on well. stack to 250/4000 for 5 minutes each.,Open master swab 23.5 turns. RIH. Cooling down N2. PT N2 lines 250/4000 psi. 1600' CTMD online with N2 600 scf/min. Increase N2 rate to 1500 scf/min. Fluid at surface at 6500' ctmd. Tag PBTD @ 9093' CTMD. 100' corrected KB depth.,Fluid return rate increasing at surface. 3238 WHP/surface N2 Well blown (/ pressure. dry. Continue pumping for 20 more minutes to dry up tubing walls. 139 bbls returned from production tubing. Close choke POOH to surface. Pump N2 AT 800 SCF/MIN. At surface. Close master and swab 2708 SITP. Town engineer required 2600 psi.100 psi additional added for N2 temp change.,Previous day attempted to fill IA and used two tank volumes of fluid from field triplex pump. Pressured up IA 4 times throughout day and bleed down to lubricate and bleed air from IA. IA was not full. Started holding pressure. Started 30 minute test at 13:01 112665 psi Mechanical gauge on triplex pump holding without bobbles or change.,Electronic Transducer gauge would increase and decrease in This is pressure. common early in the AM when acquisition is started and pressure transducer is calibrated. Throughout the day the outside temperature increases drastically, thus causing the transducer to bobble due to thermal expansion. End pressure 2632 psi @ 1331.,SLB rigging down. Coil equipment moving to KGF. Not able to move Cruz crane until Monday morning when permit office opens. 139 bbsl returned from well bore. 186,000 scf pumped for lift. or1997 gallons 63,00 scf pumped to pressure up well to 2700 psi. or 676 gallons. 2708 psi SITP. 8/8/2017 PTW. Hold safety meeting with Crews. Discuss Reel Pick and E -line Job.,Spot in equipment., Lynden truck on location. Spot up to edge of pad. Rig up Pollard crane . Unload 20k Ib spool., Ru E -line. Make up GPT/Gamm/CCL. Stab on well. Pt lubricator 250/3500 psi. Bleed down. Open well. Initial WHP 2550 psi. RIH. Found Fluid level 9094' RKB. at Tagged PBTD at 9110'. Tied into log SCMT_CBL _8JUL17 FINAL. Send log to town. Jacob Dunston confirmed log on depth. Parked GPT tool at 9080' Bleeding down WHP of 2550 psi to drop bottom hole pressure to 2365 psi. Shut choke. SITP 1820 psi.,POOH to surface. Logging OOH. Fluid level increased from 9094'to 9082' due to ballooning of tubing while under pressure. Tagged up at surface. Close master swab. Break down GPT/Gamma/CCL Make up 20' gun 2.875" EHC 6 SPF Connex Deep Penetrators. RIH. Log interval. Send Kalotsa #4 Pert Tie in log 8-8-18 to town. Confirmation depth. CCL to top shot 7'. Drop down and pick up to 9049'.,Shoot 20' Duns from 9056'-9076' SITP/WHP prior to shooting 1803 psi. Fired Start POOH. guns. I one hour while POOH we had a 52 psi increase. Tagged up at surface. Shut in well. SITP 1855 psi. WHP still climbing. RDMO Pollard E -line. Turn well over to Production. 8/25/2017 Arrive at Susan Dione office. Obtain PTW and discuss job procedure. Mobs to Iocation.,Fire up and rig up. Load guns. Top shot to CCL confirmed 7.8'. Stab on well. PT stack 250/3500 psi. Open swab 23.5 turns. RIH. Initial WHP 2617 psi SITP-Town confirmed Correlation log on depth. parked at 9048.2 with CCL Puts top shot 9056'-9076'. WHP 2641. Fire 2 7/8" x20' guns loaded with 6 SPF with GEO connex charges. POOH to surface. No notice in change of WHP gauge. Tagged up. Close swab. Bleed down off Guns pop well. dry. Bull noze on bottom of spent gun only dry pert debris. Rig down and Move to Kalotsa #3. Re -o en 4 and ush fluid awe to K-3.,Final taken WHP 2632 net and still climbin 8/31/2017 . Mobe to location. PTW and JSA Spot and rig up lubricator. PT lubricator to 250 psi low and 3500 psi high., RIH w/2-7/8"x8HC Connex 6 spf, 60 deg , phase pert gun, tie into HLB Pert log dated 25 Aug 2017 and tag at 9094'. Run correlation log and send to town. log was 2' low. Was told to perf from 9037' to 9045'. Spotted gun and fired with well flowing 642K at 756 psi. After 5 min well flow 652K at 756 psi. POOH. All shots fired. Gun was wet. Well Flowing 618K at 756 psi. Fired gun at 1112 hrs.,RIH w/2 -7/8"x8' HC Connex , 6 spf, 60 deg phase perf gun, tie into first correlation log. Spot gun from 9037'to 9045' and re-perf zone with well flowing 630K at 756 psi. After 5 min well flowing from 630K up to 648K and in-between at 756 psi. POOH. All shots fired and gun wet. Fired at 1340 has. Ri I down lubricator and move over to Kalotsa 3. gun 9/11!2017 Mobe to location. PTW and JSA. Rig up lubricator, PT to 250 psi low and 4500 psi high.,RIH w12 -7/8"x8' Razar HC, 6 spf, 60 deg phase and tie into pert log, Tag flowing at 9095. Ran correlation log and send to town. Was off 3' so was told to pert from 9072' to 9080' (proposed zone was 9075' to 9083'). Spotted gun with well 582K at 762 psi. Fired gun and after 5 min no change in flow or POOH. pressure. All shots fired. Gun was dry.,RIH w/2 -7/8"x13' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to pert from 9042' to 9055'. Spotted gun with well flowing 579K at 762.9 psi. Fired gun and after 5 min flow was 713K at 764.1. After 8 min flow was 746K at 764 psi. POOH. All shots fired and gun was dry.,RIH w/2 -7/8"x14' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to pert from 9021' to 9035'. Spotted gun with well flowing 823.71K 767 gun at psi. Fired and after 5 min flow was 845K at 767 psi. POOH. All shots fired. Gun was wet. Well is flowing 810K at 762 1 down lubricator and turn well back to Field, Hilcorp Alaska, LLC Ninilchik Unit Kalotsa Kalotsa 4 50133206650000 Sperry Drilling Definitive Survey Report 05 June, 2017 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well Kalotsa 4 Project: Nmilchik Unit TVD Reference: Kalotsa 4 WP05 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 4 WP05 @ 144.50usft Well: Kalotsa 4 North Reference: True Wellbore: Kalotsa 4 Survey Calculation Method: Minimum Curvature Design: Kalotsa4 Database: Sperry EDM - NORTH US+CANADA 18.00 ik Unit 0.00 18.00 m: LGeoDartum: Plane 1927 (Exact solution) 7AIaskt.C92� System Datum: Mean Sea Level 209,881.34 27 (NADCON CONUS) 0.00 Using Well Reference Point 196.87 one 04 295.62 Using geodetic scale factor 52.37 0.17 -0.35 2,233,554.23 Well Kalotsa 4 0.37 MWD+SC+sag(1) Well Position +N/S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Kalalsa 4 Magnetics Model Name Sample Date BGGM2016 5/13/2017 Design Kalotsa 4 Audit Notes: Version: 1.0 Phase: vertical Section: Depth From (TVD) (usft) Survey Program Date 6/5/2017 From To (usft) (usft) Survey(Wellbore) 196.87 1,466.34 MWD+SC+sag (1) (Kalotsa 4) 1,562.08 9,182.50 MWD+SC+sag(2)(Kalotsa 4) Survey 2,233,554.05 usft Latitude: 209,881.34 usft . Longitude: 144.50 usft Ground Level: Declination Dip Angle r) (•) ACTUAL +N/S (usft) 0.00 Tool Name MWD+SC+sag MWD+SC+sag 15.68 73.12 Tie On Depth: +E/ -W (usft) 0.00 18.00 Direction N 277.46 60" 6' 15.659 N 151D 35'23.806 W . 126.50 usft Field Strength wn 55,186 Description Survey Date Fixed:v2:standard dec& axial correction+sag 05/13/2017 Fixed:v2:standard dec & axial correction +sag 05/22/2017 MO Inc Azi TVD TVDSS +N/S +E/ -W Map Northing Map Easting DIS vertical Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/loo') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -126.50 0.00 0.00 2,233,554.05 209,881.34 0.00 0.00 UNDEFINED 196.87 0.25 295.62 196.87 52.37 0.17 -0.35 2,233,554.23 209,881.00 0.14 0.37 MWD+SC+sag(1) 260.48 0.51 303.69 260.48 115.98 0.39 -0.71 2,233,554.45 209,880.64 0.42 0.76 MWD+SC+sag(1) 323.54 0.77 297.82 323.53 179.03 0.74 -1.32 2,233,554.82 209,880.04 0.42 1.41 MWD+SC+sag(1) 385.21 1.16 310.50 385.20 240.70 1.34 -2.16 2,233,555.44 209,879.21 0.72 2.32 MWD+SC+sag(1) 447.10 3.44 301.31 447.03 302.53 2.71 4.23 2,233,556.86 209,877.18 3.72 4.54 MWD+SC+sag(1) 509.57 4.60 302.85 509.35 364.85 5.04 -7.93 2,233,559.28 209,873.54 1.86 8.52 MWD+SC+sag(1) 572.45 6.31 302.77 571.94 427.44 8.28 -1296 2,233,562.64 209,868.59 2.72 13.92 MWD+SC+sag if) 634.65 8.78 300.71 633.60 489.10 12.56 -19.91 2,233,567.08 209,861.74 3.99 21.37 MWD+SC+sag(1) 697.24 11.02 297.52 695.25 550.75 17.76 -2933 2,233,5/2.51 209,852.45 3.68 31.38 MWD+SC+sag(1) 757,07 12.79 292.75 753.79 609.29 22.96 40.50 2,233,577.98 209,841.40 3.38 43.14 MWD+SC+sag(1) 819.00 15.09 289.57 813.90 669.40 28.32 -54.42 2,233,583.67 209,827.62 3.91 57.64 MWD+SC+sag(1) 88169 17.13 289.24 874.12 729.62 34.09 -70.83 2,233,589.83 209,811.35 3.26 74.66 MWD+SC+sag(1) 6/512017 6:2g:31PM Page 2 COMPASS 5000.1 Build 81 Company: Hilcorp Alaska, LLC Project: Ninitchik Unit Site: Kalotsa Well: Kalotsa 4 Wellbore: Kalotsa 4 Design: Kalotsa 4 Survey Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Kalotsa 4 Kalotsa 4 WP05 @ 144.50usft Kalotsa 4 WP05 @ 144.50usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Map MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS (usft) (°) (°) (usft) (use) (usft) (usft) (ft) (ft) (°/100') 944.58 20.10 287.63 933.71 789.21 40.42 -89.88 2,233,596.62 209,792.46 4,79 1,005.77 23.58 286.12 990.50 846.00 47.00 -111.66 2,233,603.72 209,770.84 5.76 1,068.60 26.84 285.94 1,047.34 902.84 54.39 -137.38 2,233,611.73 209,745.31 5.19 1,132.40 29.22 286.22 1,103+65 959.15 62.70 -166.19 2,233,620.72 209,716.71 3.74 1,195.99 32.52 287.28 1,158.23 1,013.73 72.11 -197.42 2,233,630.89 209,685.71 5.26 1,256.49 3595 287.51 1,208.51 1,06401 82.17 -229.52 2,233,641.72 209,653,86 4.19 1,318.72 38.08 288.47 1,258.49 1,113.99 93.63 -264.77 2,233,654.02 209,618.90 4.95 1,380.56 40.35 288.67 1,306.39 1,161.89 10608 -301.83 2,233.667,36 209,582.15 3.68 1,442.68 43.19 288.49 1,352.72 1,208.22 119.26 -341.05 2,233,681.48 209,543.26 4.58 1,466.34 44.08 288.54 1,369.84 1,225.34 124.45 -356.54 2,233,687.04 209,527.91 3.76 1,562.08 46.64 289.29 1,437.11 1,292.61 146.54 420.97 2,233,710.67 209,464.02 2.73 1,625.46 47.39 288.34 1,480.32 1,335.82 16149 464.86 2,233,726.67 209,420.51 1.61 1,718.84 53.88 289.44 1,539.52 1,395.02 184.88 -533.11 2,233,751.70 209,352.83 7.01 1,748.85 54.57 289.83 1,557.07 1,412.57 193.06 -556.05 2,233,760.43 209,330.10 2.53 1,810.46 54.25 289.72 1,592.92 1,448.42 210.01 -603.19 2,233,778.51 209,283.38 0.54 1,87327 53.19 289.04 1,630.09 1,485.59 226.81 -65095 2,233,79646 209,236.04 1.90 1,936.36 53.90 286.66 1,667.57 1,523.07 243.21 -698.98 2,233,814.00 209,188.42 123 1,999.76 51.56 288.14 1,705.96 1,561.46 259.14 -746.85 2,233,831.08 209,140.95 3.75 2,060.86 52.07 288.22 1,743.74 1,59924 274.12 -792.47 2,233,847.15 209,095.70 0.84 2,123.71 52.65 287.67 1,782.12 1,637.62 28945 -039.82 2,233,863.62 209,048.73 1.15 2,185+61 52.96 286.73 1,819.54 1,675.04 304.03 -886.92 2,233,879.33 209,001.99 1.31 2,247.16 53.42 286.37 1,856.42 1,711.92 318.07 -934.16 2,233,894.50 208,955.11 0.88 2,308.84 54.02 286.04 1,892.92 1,748.42 331.95 -981.91 2,233,909.52 208,907.71 1.06 2,372.53 53.10 287.44 1,930.75 1,786.25 346.70 -1,030.97 2,233,925.45 208,859.02 2.28 2,433.86 53.27 286.92 1,967.50 1,823.00 361.20 -1,077.88 2,233,941.08 208,812.47 0.73 2,495.32 52.27 288.32 2,004.68 1,860.18 376.01 -1,124.52 2,233,957.00 208,766.20 2.44 2,559.35 52.81 287.75 2,043.63 1,899.13 391.75 -1,172.85 2,233,973.90 208,718.27 1.10 2,621.18 52.27 290.61 2,081.24 1,936.74 407.86 -1,219.19 2,233,991.12 208,672.32 3.77 2,683.82 52.19 290.80 2,119.60 1,975.10 425.37 -1,265.51 2,234,009.74 208,626.44 0.27 2,745.90 53.08 292.37 2,157.28 2,012.78 443.52 -1,311.39 2,234,028.99 208,581.01 2.47 2,807.55 53.80 291+60 2,194.00 2,049.50 462.06 -1,357.30 2,234,04863 208,535.55 1.54 2,869.48 54.43 291.50 2,230.30 2,085.80 480.49 -1,403.97 2,234,068.17 208,489.34 1.03 2,931.87 55.12 290.78 2,266.29 2,121.79 498.87 -1,451.51 2,234,087.69 208,442.26 1.45 2,993.97 5380 289.87 2,302.39 2,157.89 516.42 -1,498.89 2,234,106.38 208,395.32 2.44 3,055.65 53.35 288.84 2,339.01 2,194.51 532.87 -1,545.71 2,234,123.95 208,348.90 1.53 3,117.70 54.34 288.53 2,375.62 2,231.12 548.92 -1,593.17 2,234,141.14 208,301.84 1.65 3,180.78 52.48 288.03 2,413.22 2,268.72 564.81 -1,641.26 2,234,158.18 208,254.15 3.02 3,242.33 51.01 286.18 2,451.33 2,306.83 579.03 -1,687.45 2,234,173.51 208,208.32 3.36 3,305.01 49.56 285.56 2,491.38 2,346.88 592.22 -1,733.83 2,234,187.80 208,162.27 2.44 3,367.13 47.80 285.13 2,532.39 2,387.89 604.57 -1,778.81 2,234201.23 208,117.60 2.88 Vertical Section (ft) Survey Toot Name 94.37 MWD+SC+sag(1) 116.82 MWD+SC+sag(1) 143.28 MWD+SC+sag(1) 172.92 MWD+SC+sag(1) 205.11 MWD+SC+sag(1) 238.25 MWD+SC+sag(1) 274.69 MWD+SC+sag(1) 313.05 MWD+SC+sag(1) 353.65 MWD+SC+sag(1) 369.67 MWD+SC+sag(1) 436.43 MWD+SC+Sag(2) 481.89 MWD+SC+sag(2) 552.60 MWD+SC+sag(2) 576.41 MWD+SC+sag(2) 625.35 MWD+SC+sag(2) 674.89 MWD+SC+sag(2) 724.64 MWD+SC+sag(2) 774.17 MWD+SC+sag(2) 821.36 MWD+SC+sag(2) 870.29 MWD+SC+sag(2) 918.89 MWD+SC+sag(2) 967.55 MWD+SGsag(2) 1,016.69 MWD+SC+sag(2) 1,067.26 MWD+SC+sag(2) 1,115.65 MWD+SC+sag(2) 1,163.82 MWD+SC+sag(2) 1,213.78 MWD+SC+sag(2) 1,261.83 MWD+SC+sag(2) 1,310.03 MWD+SC+sag(2) 1,357.87 MWD+SC+sag(2) 1,405.81 MWD+SC+sag(2) 1,45447 MWD+SC+sag(2) 1,503.99 MWD+SC+sag(2) 1,553.25 MWD+SC+sag(2) 1,601.82 MWD+SC+sag(2) 1,650.96 MWD+SC+sag(2) 1,700.70 MWD+SC+sag(2) 1,748.35 MWD+SC+sag(2) 1,796.04 MWD+SC+Sag(2) 1,842.25 MWD+SC+sag(2) 675/2017 6:29:31PM Page 3 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Kalotsa 4 Project: Nmilchik Unit ND Reference: Kalotsa 4 WPO5 @ 144,50usft Site: Kalotsa MD Reference: Kalotsa 4 WP05 @ 144,50usft Well: Kalotsa 4 North Reference: True Wellbore: Kalotsa 4 Survey Calculation Method: Minimum Curvature Design: Kalotsa 4 Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/.W Northing Easting DIS Section (usft) (•) (°) (usft) (usft) (usft) (usft) (R) (ft) (°/100') (ft) Survey Tool Name 3,429.61 46.67 283.69 2,574.82 2,430.32 615.99 -1,823.24 2,234,213.72 208,073.46 2.48 1,887.78 MWD+SC+sag(2) 3,492.62 45.64 283.25 2,618.46 2,473.96 626.57 -1,867.43 2,234,225.36 208,029.54 1.71 1,932.97 MW13+SC+sag(2) 3,551.99 45.90 282.88 2,659.88 2,515.38 636.19 -1,908.87 2,234,235.97 207,988.34 0.62 1,975.31 MWD+SC+sag(2) 3,615.00 44.66 282.32 2,704.21 2,559.71 645.96 -1,952.56 2,234,246.79 207,944.90 2.07 2,019.90 MWD+SC+sag(2) 3,67288 43.87 281.31 2,749,24 2,604.74 654.95 -1,995.52 2,234,256.81 207,902.17 1.68 2,063.66 MWD+SC+sag(2) 3,739.83 42.89 280.41 2,794.27 2,649.77 662.97 -2,037.30 2,234,265.83 207,860.59 1.87 2,106.13 MWD+SC+sag(2) 3,803.47 41.78 280.16 2,841.31 2,696.81 670.62 -2,079.47 2,234,274.50 207,818.61 1.76 2,148.94 MWD+SC+sag(2) 3,866.33 39.99 279.53 2,888.83 2,744.33 67266 -2,120.01 2,234,282.51 207,778.26 2.92 2,190.05 MWD+SC+sag(2) 3,927.79 38.45 278.90 2,936.45 2,791.95 683.89 -2,158.37 2,234,289.66 207,740.06 2.59 2,228.89 MWD+SC+sag(2) 3,990.53 38.64 278.05 2,985.52 2,841.02 689.65 -2,197.03 2,234,296.35 207,701.55 0.90 2,26].98 MWD+SC+sag(2) 41052.39 37.92 275.94 3,034.08 2,889.58 694.32 -2,235.06 2,234,301.93 207,663.64 2.41 2,306.29 MWD+SC+sag(2) 4,114.64 36.80 273.38 3,083.56 2,939.06 69240 -2,272.71 2,234,305.92 207,626.08 3.08 2,344.02 MWD+SC+sag(2) 41176.99 35.63 271.74 3,133.86 2,989.36 699.05 -2,309.50 2,234,308.45 207,589.34 2.44 2,380.72 MWD+SC+sag(2) 4,239.76 34.92 269.58 3,185.11 3,040.61 69948 -2,345.74 2,234,309.75 207,553.11 2.29 2,416.71 MWD+SC+sag(2) 4,301.54 33.76 26204 3,236.12 3,091.62 69x.46 -2,380.57 2,234,309.57 207,518.27 2.98 2,451.11 MWD+SC+sag(2) 4,363.37 32.85 265.00 3,28].80 3,143.30 696.11 -2,414.44 2,234,308.04 207,484.36 2.33 2,484.38 MWD+SC+sag(2) 4,424.75 32.29 263.82 3,339.53 3,195.03 692.89 -2,447.32 2,234,305.61 207,451.41 1.38 2,516.57 MWD+SC+sag(2) 4,485.95 32.01 2WA4 3,391.34 3,24684 689.17 -2,479.67 2,234,302.67 207,418.98 0.82 2,548.16 MWD+SC+sag(2) 4,535.64 32.35 262.96 3,433.40 3,288.90 685.94 -2,505.94 2,234,300.08 207,392.64 0.69 2,573.79 MWD+SC+sag(2) 4,597.95 31.39 261.79 3,486.32 3,341.82 681.58 -2,538.55 2,234,296.50 207,359.94 1.83 2,605.55 MWD+SC+sag(2) 4,659.50 30.05 261.28 3,539.23 3,394.73 676.96 -2,569.65 2,234,292.63 207,328.74 2.22 2,635.79 MWD+SC+sag(2) 4,722.54 29.19 259.74 3,594.03 3,449.53 671.83 -2,600.38 2,234,288.24 207,297.89 1.82 2,665.59 MWD+SC+sag(2) 4,786.11 28.62 259.00 3,651.43 3,506.93 665.98 -2,631.53 2,234,283.14 207,266.61 1.03 2,695.72 MWD+SC+sag(2) 4,851.15 27.37 258.57 3,707.10 3,562.60 660.23 -2,660.55 2,234,278.09 207,237.46 2.01 2,723.75 MWD+SC+sag(2) 4,912.51 26.15 256.93 3,761.88 3,617.36 654.38 -2,687.55 2,234,272.89 207,210.33 2.32 2,749.76 MWD+SC+sag(2) 4,975.88 23.34 255.99 3,819.43 3,674.93 648.18 -2,713.34 2,234,267.31 207,184.40 4.48 2,774.53 MWD+SC+sag (2) 5,038.69 21.63 255.84 3,877.46 3,73296 642.33 -2,736.63 2,234,262.03 207,160.96 2.72 2,796.87 MWD+SC+sag (2) 5,104.71 20.17 255.92 3,939.14 3,794.54 636.59 -2,759.47 2,234,256.63 207,137.99 2.21 2,818.77 MWD+SC+sag(2) 5,165.05 18.10 255.00 3,996.14 3,851.64 631.63 -2,778.62 2,234,252.34 207,118.73 3.47 2,837.11 MWD+SC+sag(2) 5,227.12 17.29 257.14 4,055.27 3,910.77 627.08 -2,796.93 2,234,248.23 207,100.32 1.67 2,854.67 MWD+SC+sag(2) 5,290.39 16.35 257.87 4,115.84 3,97134 623.12 -2,814.80 2,234,244.70 207,082.36 1.52 2,871.88 MW13+SC+sa9(2) 5,352.61 15.40 25964 4,175.68 4,031.18 619.79 -2,83149 2,234,241.78 207,065.60 1.71 2,887.99 MWD+SC+sag(2) 5,419.67 14.58 261.09 4,240.46 4,095.96 616.88 -2,848.59 2,234,239.28 207,048.43 1.34 2,904.57 MWD+SC+seg(2) 5,480.65 13.09 263.81 4,299.67 4,155.17 614.95 -2,86394 2,234,237.69 207,033.94 2.67 2,918.64 MWD+SC+sag(2) 5,544.39 12.75 262.54 4,361.80 4,217.30 613.26 -2,877.19 2,234,236.34 207,019.75 0.69 2,932.45 MWD+SC+sag(2) 5,609.21 12.95 261.96 4,424.99 4,280.49 611.31 -2,891.47 2,234,234]4 207,005.43 0.37 2,946.37 MWD+SC+sag(2) 5,671.01 13.57 262.63 4,485,15 4,340.65 609.42 -2,905.52 2,234,233.18 206,991.34 1.03 2,960.05 MWD+SC+sag(2) 5,737.89 13.41 263.30 4,550.18 4,405.68 607.50 -2,921.00 2,234,231.64 206,975.81 0.33 2,975.15 MWD+SC+sag(2) 5,800.29 13.42 264.36 4,610.86 4,46638 605.95 -2,935.39 2,234,230.44 206,961.39 0.39 2,989.22 MWD+SC+sag(2) 5,863.51 12.83 258.98 4,672.45 4,527.95 603.89 -2,949.58 2,234,228.71 206,947.15 2.14 3,003.02 MWD+SC+sag(2) 615/2017 6:29:31PM Page 4 COMPASS 5000,1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: _ Well KaloNa 4 Project: Ninilchik Unit TVD Reference: Kalolsa 4 WP05 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 4 WP05 @ 144.50usft Well: Kalotsa 4 North Reference: True Wellbore: Kalotsa 4 Survey Calculation Method: Minimum Curvature Design: Kalotsa 4 Database: Sperry EDM - NORTH US + CANADA Survey Map Map vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting OLS Section (usft) (') V) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Too[Name 5,925.74 12.31 257.39 4,733.19 4,588.69 601.12 -2,962.84 2,234,226.27 206,933.83 1.00 3,015.81 MWD+SC+sag(2) 5,988.01 12.37 257.68 4,794.02 4,649.52 598.24 -2,975.83 2,234,223.71 206.920.77 0.14 3,028.32 MWD+SC+sag(2) 6,054.28 1269 257.15 4,858.78 4,714.28 595.19 -2,98954 2,234,220.98 206,907.00 0.46 3,041.51 MWD+SC+sag(2) 6,117.14 11.77 256.96 4,920.29 4,775.79 592.28 -3,002.20 2,234,218.37 206,894.27 0.51 3,053.69 MWD+SC+sag(2) 6,179.80 11.45 257.91 4,981.66 4,837.16 589.53 -3,014.51 2,234,215.93 206,881.90 0.59 3,065.53 MWD+SC+sag(2) 6,243.04 11.47 257.37 5,043.64 4,899.14 58684 -3,026.78 2,234,213.53 206,869.57 0.17 3,077.35 MWD+SC+sag(2) 6,306.65 11.30 257.45 5,10680 4,961.50 584.10 -3,039.04 2,234,211.09 206,857.25 0.27 3,089.15 MWD+SC+sag(2) 6,369.03 11.52 257.10 5,167.15 5,022.65 581.39 -3,051.07 2,234,208.66 206,845.15 0.37 3,100.73 MWD+SG+sag(2) 6,431.67 12.09 258.11 5,228.46 5,083.96 578.64 -3,063.59 2,234,206.22 206,832.57 0.97 3,112.78 MW13+SC+sag(2) 6,494.40 11.66 257.25 5,289.85 5,145.35 575.89 -3.076+20 2,234,203.77 206,819.90 0.74 3,124.93 MWD+SC+sag(2) 6,554.72 11.36 25594 5,348.96 5,20446 573.10 -3,087.91 2,234,201.26 206,808.13 0.66 3,136.18 MWD+SC+sag(2) 6,617.95 11.22 260.02 5,410.97 5,266.47 570.52 -3,100.01 2,234,198.98 206,795.97 1.28 3,147.84 MWD+SC+seg(2) 6,683.76 10.82 261.59 5,475.56 5,331.06 568.50 -3,112.42 2,234,197.26 206,783.51 0.76 3,159.89 MWD+SC+sag(2) 6,746.77 11.30 262.34 5.537.40 5,392.90 566.82 -3,124.39 2,234,195.86 206,771.50 0.80 3,171.54 MWD+SC+sag(2) 6,808.23 11.57 262.37 5,597.64 5,453.14 565.20 x,136.47 2,234,194.53 206,759.39 0.44 3,183.30 MWD+SC+sag(2) 6,869.55 11.32 261.05 5,657.74 5,513.24 563.44 -3,148.51 2,234,193.07 206,747.31 0.59 3,195.01 MWD+SC+sag(2) 6,932.70 12.18 260.56 5,719.57 5,575.07 561.39 -3,161.20 2,234,191.32 206,734.57 1.37 3,207.33 MWD+SC+sag(2) 6,999.63 12.09 260.44 5,785.00 5,640.50 559.06 -3,175.08 2,234,189.33 206,720.64 0.14 3,220.79 MWD+SC+sag(2) 7,064.93 12.71 263.40 5,848.78 5,704.28 557.10 -3,188.96 2,234,187.70 206,706.72 1.36 3,234.30 MWD+SC+sag(2) 7,127.43 13.17 263.30 5,909.69 5,765.19 555.48 -3,202.86 2,234,186.42 206,692.79 0.74 3,247.87 MWD+SC+sag(2) 7,190.09 13.27 260.53 5,970.69 5,826.19 553.47 -3,217.04 2,234,184.74 206,678.56 1.02 3,261.67 MWD+SC+sag(2) 7,253.24 12.80 258.33 6,032.22 5,887.72 550.86 x,231.04 2,234,182.47 206,664.50 1.08 3,275.22 MWD+SC+sag(2) 7,316.65 12.73 259.93 6,094.06 5,949.56 548.22 -3,244.80 2,234,180.16 206,650.68 0.57 3,288.51 MWD+SC+sag(2) 7,378.67 13.41 260.57 6,154.47 6,009.97 545.84 ],258.62 2,234,178.12 206,636.81 1.12 3,301.91 MWD+SC+sag(2) 7,441.98 13.36 260.81 6,216.06 6,071.56 543.47 -3,273.09 2,234,176.10 206,622.29 0.12 3,315.94 MWD+SC+sag(2) 7,501.67 13.05 261.81 6,274.17 6,129.67 541.41 -3,286.57 2,234,174.36 206,608.77 0.65 3,329.04 MWD+SC+sag(2) 7,564.91 12.17 259.61 6,335.89 6,191.39 539.19 -3,300.19 2,234,172.47 206,595.09 1.59 3,342.26 MWD+SC+sag(2) 7,627.42 11.91 260.38 6,397.02 6,252.52 536.92 -3,313.03 2,234,170.52 206,582.20 0.49 3,354.70 MWD+SC+sag(2) 7,690.08 12.11 261.72 6,458.31 6,313.81 534.90 -3,325.91 2,234,168.80 206,569.28 0.55 3,367.21 MWD+SC+sag(2) 7,750.88 13.26 256.77 6,517.63 6,373.13 532.38 -3,339.01 2,234,166.60 206,556.12 2.60 3,379.87 MWD+SC+sag(2) 7,812.18 13.30 255.05 6,577.29 6,432.79 528.96 -3,352.66 2,234,163.50 206,542.39 0.65 3,392.96 MWD+SC+sag(2) 7,873.88 13.43 254.88 6,637.32 6,492.82 525.26 x,366.44 2,234,160.14 206,528.53 0.22 3,406.14 MWD+SC+sag(2) 7,936.04 12.46 25583 6,697.90 6,553.40 521.73 -3,379.91 2,234,156.94 206.514.98 1.60 3,419.04 MWD+SC+sag(2) 7,997.93 12.31 256.46 6,758.35 6,613.85 518.55 x,392.80 2.234,154.07 206,502.02 0.33 3,431.41 MWD+SC+sag(2) 8,060.55 11.25 256.33 6.819.65 6,675.15 515.55 -3,405.22 2,234,151.36 206,489.52 1.69 3,443.34 MWD+SC+sag(2) 8,123.07 11.53 256.53 6,880.94 6,73644 512.65 -3,417.22 2,234,148.75 206,477.45 0.45 3,454.86 MWD+SC+sag(2) 8,185.30 12.19 259.16 6,941.84 6,797.34 509.96 ],429.73 2,234,146.37 206,464.89 1.37 3,466.91 MWD+SC+seg(2) 8,246.50 13.38 256.77 7,001.52 6,857.02 507.13 -3,442.97 2,234,143.85 206,451.59 2.13 3,479.67 MWD+SC+sag(2) 8,311.44 13.35 256.64 7,064.70 6,920.20 50368 -3,457.57 2,234,140.76 206,436.90 0.07 3,493.70 MWD+SC+sag(2) 8,373.26 13.17 254.42 7,124.87 6,980.37 500.14 ],471.30 2,234,137.55 206,423.09 0.87 3,506.86 MWD+SC+sag(2) 67&2017 6:29:31PM Page 5 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well Kalotsa 4 Project: Ninilchik Unit ND Reference: Kalotsa 4 WP05 @ 144.50usft Site: Kalotsa MD Reference: Kalotsa 4 WP05 @ 144.50usft Well: Kalotsa 4 North Reference: True Wellbore: Kalotsa 4 Survey Calculation Method: Minimum Curvature Design: Kalotsa 4 Database: Sperry EDM - NORTH US+ CANADA Survey MD Inc Axi NO +N/-S +E/ -W Map Map Northing Map Easting DLS vertical Section (usft) (°) (°) (usft) (usft) (usft)usft ( ) (ft) (ft) (°/100') (ft) Survey Tool Name 8,434.53 12.59 255.10 7,184.60 7,040.10 496.54 3,484.48 2,234,134.27 206,409.83 0.98 3,51945 MWD+SC+sag(2) 8,497.19 12.00 253.45 7,245.82 7,101.32 492.93 3,497.32 2,234,130.97 206,396.91 1.10 3,531.72 MWD+SC+sag(2) 8,558.67 11.26 249.93 7,306.04 7,161.54 489.05 -3,509.09 2,234,127.37 206,385.05 1.67 3,542.88 MWD+SC+sag(2) 8,619.65 1092 247.38 7,365.88 7,221.38 484.79 3,520.01 2,234,123.37 206,374.03 0.98 3,553.16 MWD+SC+sag(2) 8,681.99 10.79 245.18 7,427.11 7,282.51 480.07 -3,530.76 2,234,118.91 206,363.17 0.70 3,563.20 MWD+SC+1ag(2) 8,744.58 10.43 241.63 7,488.63 7,344.13 474.92 -3,541.06 2,234,114.01 206,352.75 1.19 3,572.75 MWD+SC+sag(2) 8,806.54 10.27 241.37 7,549.58 7,405.08 469.60 -3,550.84 2,234,108.94 206,342.84 0.27 3,581]6 MWD+SC+sag(2) 8,868.90 9.84 240.48 7,610.98 7,466.48 464.31 3,560.36 2,234,103.86 206,333.20 0.73 3,590.51 MWD+SC+sag(2) 8,930.81 9.54 238.39 7,672.01 7,527.51 459.02 -3,569.33 2,234,098.80 206,324.10 0.75 3,59872 MWD+SC+sag(2) 8,994.58 9.80 23537 7,734.87 7,590.37 453.16 3,578.30 2,234,093.16 206,315.00 0.89 3,606.85 MWD+SC+sag(2) 9,056.87 9.75 233.94 7,796.26 7,651.76 447.05 -3,586.92 2,234,087.26 206,306.23 0.40 3,614.61 MWD+SC+sag(2) 9,119.67 962 230.83 7,858.17 7,713.67 440.60 -3,595:29 2,234,081.01 206,297.71 0.86 3,622.07 MWD+SG+a,(2) 9,182.50 8.87 230.74 7,920.18 7,77568 434.22 -3,603.11 2,234,074.82 206,289.73 1.19 3,628.99 MWD+SC+sag(2) 9,221.00. 8.87 230.74 7,958.22 • 7,813.72 430.46 -3,607.71 2,234,071.18 206,285.05 0.00 3,633.06 PROJECTED to To Checked By: ial>aa'0 151 lPslZ`W- Approved 8 Michael Calkins ,^ PP Y Date: R/F/9f197 675/2017 6:29:31PM Page 6 COMPASS 5000.1 Build 81 H11corp Energy Company CASING & CEMENTING REPORT Lease & Well No, NINU Kalotsa 4 Date Run 17 -May -17 County State Alaska Supv. C. Montague / A. Dorr CASING RECORD Surface � TO 1,502.00 Shoe Depth: 1,491.43 PBTD: Na its. Delivered No. its. Run 36 Length Measurements W/O Threads RKB 18.00 Ftg. Delivered Ftg, Run 1,470.31 Ftg. Cut A Ftg. Balance RKB to BHF 20.65 RKB to CHF No. its. Returned Ftg. Returned RKB to THF Csg Wt. On Slips: Rotate Csg Fluid Description: Liner hanger Info(Make/Model): Liner hanger test pressure: Centralizer Placement ------ • sr- ,. -.e rv..'.w No. Firs to Run: 30,000 Type of Shoe: Antelope Casing Crew: _ Yes X No Recip Csg _ Yes X No Ft. Min. Spud Mud Liner top Packer?: Floats Held 17 total centralizers ( 2 cents on jt #1, 1 perjt on jt #2 & #3 & 1 cent every otherjt from #5 to #29) 5 Weatherford 9 PPG _ Yes No _Yes _ No Casing (Or Liner) Detail CEMENTING REPORT Shoe @ 1491.43 Setting Depths its. Component Size Wt. Grade THD Make Length Bottom Top Shoe 85/8 Type: Type 1/II BTC Antelope 1.46 1,491.43 1,489.97 2 Casin 75/8 29.7 L-80 BTC USS 80.72 1,489.97 1,409.25 Volume pumped (BBLs) Float Collar 8 5/8 Post Flush (Spacer) BTC Antelo a 1.28 1,409.25 1,407.97 33 Casin 75/8 29.7 L-80 BTC USS 1,322.43 11407.97 85.54 Pump used for disp: Halliburton Cement Casing Pup it 7 5/8 29.7 L-80 BTC USS 19.89 85.54 65.65 1 Casing 7 5/8 29.7 L-80 BTC USS 40.23 65.65 25.42 Qn Wt Hanger & Pup It n., u,...� 7 5/8 29.7 L-80 BTC Cactus 4.30 25.42 21.12 Csg Wt. On Slips: Rotate Csg Fluid Description: Liner hanger Info(Make/Model): Liner hanger test pressure: Centralizer Placement ------ • sr- ,. -.e rv..'.w No. Firs to Run: 30,000 Type of Shoe: Antelope Casing Crew: _ Yes X No Recip Csg _ Yes X No Ft. Min. Spud Mud Liner top Packer?: Floats Held 17 total centralizers ( 2 cents on jt #1, 1 perjt on jt #2 & #3 & 1 cent every otherjt from #5 to #29) 5 Weatherford 9 PPG _ Yes No _Yes _ No CEMENTING REPORT Shoe @ 1491.43 FC @ 1,407.97 Top of Liner #N/A Preflush (Spacer) Type: Clean Spacer III Density (ppg) 10 Volume pumped (BBLs) 31 Lead Slurry Type: Type 1/II Sacks: 226 Yield: 2.48 Density (ppg) 12 Volume pumped (BBLs) 100 Mixing / Pumping Rate (bpm): 5 Tail Slurry Type: Class G Sacks: 181 Yield: 1.23 Density (ppg) 15.4 Volume pumped (BBLs) 39.5 Mixing / Pumping Rate (bpm)' 5 Post Flush (Spacer) Type: Water Density (ppg) 8.34 Rate (bpm): 3 Volume: 10 Displacement: Type: Drilling fluid Density (ppg) 9.1 Rate (bpm): 6 Volume (actual / calculated): 56/55 FCP (psi): 420 Pump used for disp: Halliburton Cement Bump Plug? X Yes No Bump press 1180 Casing Rotated? _Yes X No Reciprocated? _Yes _ X No % Returns during job 100 Cement returns to surface? X Yes _No Spacer returns? X Yes Vol to Surf 51 Cement In Place At: 12:16 Date: 5/17/2017 -No Estimated TOC: 23 Method Used To Determine TOC: Reh. Fn Calculated Cmt Vol @ 0% excess: 76.6 Total Volume cmt Pumped: 139.5 Cmt returned to surface: 51 Calculated cement left in wellbore: 88.5 OH volume Calculated: 52.7 OH volume actual: 65.1 Actual % Washout: 23.5 Make Cactus Type Single Bowl Serial No. Size 13.63 W.P. Test head to 5000 PSIG 15 MIN OK OK Remarks: LLC Hf/corp Energy Company CASING & CEMENTING REPORT Lease 8 Well No, nmelope No. Hrs to Run: Type of Shoe: Antelope Bullnose Casing Crew: Weatherford Yes X No Recip Csg _ Yes X No Ft. Min. 9.65 PPG 6% KCL/PHPA Liner top Packer?: Yes No _ Floats Held 750 hydroforms, One perloint from shoe joint to joint #146, then 23 spirogliders, one every other jnt up to jnt 163. X Yes No Casing (Or Liner) Detail Shoe@ 9212.7 FC@ 9,726.63 County Preflush (Spacer) NINU Kalotsa 4 its. Date Run 3 -Jun -17 Size Wt. State Alaska Supv. R Pederson / R Wall Length Bottom CASING RECORD (ppg) Float Shoe 5 20.0 Production DWC/C Antelope TO 9,221.00 Shoe Depth: 9,212.70 PBTD: 9,126.63 Casin No. its. Delivered 228 No. its. Run 222 No. its. Returned 6 Atlas Bradford Ftg. Delivered 9,439.70 Ftg. Run 9,193.70 Ftg. Returned 246.00 Length Measurements W/O Threads Ftg. Cut it. Fig. Balance L-80 DWC/C IRKS 18.00 IRKS to BHF 20.65 RKB to CHF 9,126.63 RKB to THF Csg Wt. On Slips: Rotate Csg Fluid Description: Liner hanger Info(Make/Model): Liner hanger test pressure: Centralizer Placement: nmelope No. Hrs to Run: Type of Shoe: Antelope Bullnose Casing Crew: Weatherford Yes X No Recip Csg _ Yes X No Ft. Min. 9.65 PPG 6% KCL/PHPA Liner top Packer?: Yes No _ Floats Held 750 hydroforms, One perloint from shoe joint to joint #146, then 23 spirogliders, one every other jnt up to jnt 163. X Yes No Casing (Or Liner) Detail Shoe@ 9212.7 FC@ 9,726.63 TOP of Liner Preflush (Spacer) Setting Depths its. Component Size Wt. Grade THD Make Length Bottom To (ppg) Float Shoe 5 20.0 L-80 DWC/C Antelope 1.40 9,212.70 9,211.30 2 Casin 41/2 12.6 L-80 DWC/C Atlas Bradford 83.36 9,211.30 9,127.94 35 Float collar 5 20.0 L-80 DWC/C Antelope 1.31 9,127,94 9,126.63 Cement returns to surface? Casing 41/2 12.6 L-80 DWC/C Atlas Bradford 611.00 9,126.63 8,515.63 RA Marker A."A" 41/2 12.6 L-80 DWC/C Atlas Bradford 19.59 8,515.63 8,496.04 24 Casing "B" 41/2 12.6 L-80 DWC/C Atlas Bradford 976.62 8,496.04 71519.42 RA Marker Jt. 41/2 12.6 L-80 DWC/C Atlas Bradford 19.98 7,519.42 7,499.53 24 Casing 4 1/2 12.6 L-80 DWC/C Atlas Bradford 989.31 7,499.53 6,510.22 RA Marker"C" 41/2 12.6 L-80 DWC/C Atlas Bradford 19.85 6,510.22 6,490.34 24 Casing 41/2 12.6 L-80 DWC/C Atlas Bradford 980.92 6,490.34 5,509.42 102 RA Marker"D" 41/2 12.6 L-80 DWC/C Atlas Bradford 19.50 5,509.42 5,489.92 Casing 41/2 12.6 L-80 DWC/C Atlas Bradford 4,167.58 .91 1,322.34 Swell packer w/ pups 6 12.6 L-80 DWC/C Baker 34.49 1,322.34 1,287.85 31 Casing 41/2 12.6 L-80 DWC/C Atlas Bradford 5,467.60 1,287.85 22.32 Hanger 103/4 20.0 L-80 DWC/C Cactus 3.32 22.32 19.00 Csg WL On Hook: Csg Wt. On Slips: Rotate Csg Fluid Description: Liner hanger Info(Make/Model): Liner hanger test pressure: Centralizer Placement: nmelope No. Hrs to Run: Type of Shoe: Antelope Bullnose Casing Crew: Weatherford Yes X No Recip Csg _ Yes X No Ft. Min. 9.65 PPG 6% KCL/PHPA Liner top Packer?: Yes No _ Floats Held 750 hydroforms, One perloint from shoe joint to joint #146, then 23 spirogliders, one every other jnt up to jnt 163. X Yes No CEMENTING REPORT Shoe@ 9212.7 FC@ 9,726.63 TOP of Liner Preflush (Spacer) Type: Clean Spacer III Density (ppg) 12 Volume pumped (BBLs) Lead Slurry Type: Type 1 -II q (ppg) 72.2 Volume pumped (BBLs) Sacks: 675 Yield:Tensity 240 Mixing / Pumping Rate (bpm):Tail SlurryType: Class GSacks: Density (ppg) 15.3 Volume pumped (BBLs) 760 Yieltl: 35.2Mixing /Pumping Rate (bpm): Post Flush (Spacer) q Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: 6% KCL Brine Density (ppg) 8.7 Rate (bpm): 7 Volume (actual / calculated): 139.75/138.5 FCP(psi): 2156 Pump used for disp: Halliburton Bump Plug? X No Bump press Casing Rotated? _yes X No Reciprocated? _Yes X No %Returns during job 100 Cement returns to surface? _Yes X Yes _ No Spacer returns? X Yes No Vol to Surf 0,2 Cement In Place At: 12:07 Date: 6/4/2017 Estimated TOC: 338 Method Used To Determine TOC: Velums Post Job Calculations: Calculated Cmt VOI @ 0% excess: Cmt returned to surface: OH volume Calculated Total Volume cmt Pumped: 0.2 Calculated cement left in wellbore: 310 342 OH volume actual: 342 Actual % Washout Hilenrl, AlamA., LLA. DATE 09/18/17 Seth Nolan GeoTech RECEIVED SEP 19 2017 AOGCC Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA Core Data CD1: . Thin Sections 9/18/20178:39 AM File folder C] Hilcorp Kalotsa 4 HH -95363 Rotary Core Dat... 9/18/2017 8:35 AM Microsoft Excel W or... 79 K8 C Hillorp Kalosta 4 HH -95363 CEC Data - 8-16... 9/18/20178:35 AM Microsoft Excel Wor... 28 KB Please include current contact information if different from above. 21 7063 28 1 05 DATA LOGGED 9 27�/201i Ivl. K. BENDER Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: V Hilearp Atanka, I.LC DATE 07/18/2017 Seth Nolan GeoTech RECEIVED JUL 19 2017 AOGCC Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 Elog Prints and Digital data Prints 2"/5" ROP-DGR-EWR- CTN-ALD MD 2"/5" DGR-EWR-CTN- ALD TVD MSCT-GR ADT -GR ECS -GR CBL-VDL-GR-CCL CD3: Mudlogs . Daily Reports DML Data . Final well Report LAS Data Log PDFs Log TIFFS Show Reports CD2: LWD i DATA LOGGED 1 A5/2011 M. K. BENDER 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 MD/TVD FINAL WELL REPORT 7/17/2017 3:40 PM File folder 7/17/2017 3:41 PM File folder 7/17/20173:41 PM File folder 7/17/2017 3:42 PM File folder 7/17/2017 3:45 PM File folder 7/17/2017 3:47 PM File folder 7/17/2017 3:40 PM File folder 21 7063 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: 1 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 na,nrp al, +ka, UA: Fax: 907 777-8510 28 4 0 9 E-mail: snolan@hilcorp.com _Log Viewers 7/6/2017 8:37 AM File folder . CGM 7/6/2017 8:37 AM File folder . Definitive Survey 7/6/2017 8:34 AM File folder EMF 7/6/2017 8:35 AM File folder LAS 7/6/2017 8:35 AM File folder . PDF 7/7/2017 8:45 PM File folder . TIFF 7/6/2017 8:38 AM File folder CD3: MSCT 2 8 4 1 0 DLIS Data 6/16/2017 9:30 AM File folder . LAS Data 6/16/2017 9:30 AM File folder . LOG Data 6/20/2017 1:20 PM File folder CD4: XPT-ADT-ECS 2 8 4 1 1 . DLIS Data 6/16/20179:33 AM File folder LAS Data 6/30/20173:20 PM File folder . Log 6/16/20179:34 AM File folder CDS: CBL 28 4 12 DLIS Data 7/18/2017 8:23 AM File folder LAS Data 7/18/20178:24AM File folder . Log 7/18/2017 8:24 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: DATE 06/29/17 To: AOGCC i t .1 Nolan Hilcorp Alaska, LL.. GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com Meredith Guhl 333 W. 711 Ave. Ste#100 Anchorage, AK 99501 1 by -711i W-11 1 .171 WELL SAMPLE INTERVAL KALOTSA 4 1500 - 2730 KALOTSA 4 2730 -4050 KALOTSA 4 4050 -5640 KALOTSA 4 5640 -6900 KALOTSA 4 6900 -8700 KALOTSA 4 8700-9221 Please include current contact information if different from above. �ql7 —Vk3 j(o« RECEIVED JUL 19 2017 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 f-4 (21t(,-7- THE STATE °fALASKA GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 4 Permit to Drill Number: 217-063 Sundry Number: 317-253 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.claska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this day of June, 2017. Sincerely, P� Cathy P Foerster Chair RBDMS �L-JUJ Z 6 2017 RECEIVED STATE OF ALASKA ,,,J 1 (� C//(-r //d ALASKA OIL AND GAS CONSERVATION COMMISSION (1%7U /, APPLICATION FOR SUNDRY APPROVALS AOGC;C c ,A �. 1 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Atter Casing 11 Other ❑ 2. Operator Name: 4. Current Well Class: 5. Permft to Orill Number. Hilcorp Alaska, LLC Exploratory ❑ Development Q• 217-063. Stratigraphic ❑ Service ❑ S. API Number. 3. Address: 3800 Centerpoint Drive, Suite 1400 Anchorage Alaska 99503 50-133-20665-00 - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 701A Will planned Perforations require a spacing exception? P P q P 9 P Yes ❑ No Q Kelotsa4 9. Property Designation (Lease Number): 10. Field/Pool(s): C061 505(SHL) / ADL384372 (BH L) Ninilchik Field - BelugaTyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 9,221' 7,958' 9,127' 7,865' —2,582 psi WA N/A Casing Length Size MDWTVDBurst Corpse Structural Conductor 120' i6" 12Y2,980psi 1,410psi Surface 1,491' 7-5/8"1,491'6,890151 4,790151 IntermediateProduction 9,213' 4-1/2" 9,213'8,430151 7,50 si Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: tubing MD (fl): 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 Packer; N/A 1,298' MD/1,242 ND; VA 12. Attachments: Proposal Summary Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑J Exploratory © Stratigraph€c ❑ Dsvdopment ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 15, 2017' OIL © WINJ ❑ WDSPL ❑ Suspended ❑ 16. verbal Approval: Date: GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ C]Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Hel eson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer hllco .com Contact Phone: 777-8420 Authorized Signature: Date: COMMISION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31`7- / Plug Integrity ❑ BOP Test l!V Mechanical Integrity Test ❑ Location Clearance El� r It (c 11 // JJ Other: - ©O C, 3c)P.E Ir`5 f C d ) " X05:, `. Post Initial Injection MIT eYes [3 No E]' n l Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: r(� - y0 7 - RBDMS t-�' JUN 1 6 2017 APPROVED APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 4/2017 n p/p�ro e t n is valid for 12 months from the date of approval. Submit Form and O R �V P pP Attachment in Duplicate ff flilc p Alaska, LU Well Prognosis Well: Kalotsa #4 Date: 6/13/2017 Well Name: Kalotsa #4 API Number: 50-133-20665-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: July 15th, 2017 Rig: Coil Unit Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 217-063 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: 1710633C Maximum Expected BHP: — 3,364 psi @ 7,823' TVD (Based on normal gradient of 0.43 psi/ft and the lowest perforation) Max. Potential Surface Pressure: — 2,582 psi @ 7,823' TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summar Kalotsa #4 is a grass roots development well targeting gas sands in the Tyonek formation. This new well reached TD on 5/27/17 and completed 6/6/17. The purpose of this work/sundry is to evaluate cement, jet the well dry with CT and perforate. Notes Regarding Wellbore Condition • Well is filled with 139.75 bbls 6% KCI. • slickline tag and make gauge ring run prior to starting work. • E -line will complete CBL prior to starting sundry work. Electronic copy of CBL to be sent to AOGCC when completed. • 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. "Ck"J- 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 Coiled Tubing Procedure (start of Sundry work) I. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. If slickline or eline tags cement shallower than 9_`. Follow steps 2-6 & 9-11.� 2. MU Mill and Motor BHA. � ? "� fF 7t i6 11 3. RIH and mill cement and cleanout t 0' MD �I I Yd /Gt !� \(oC`((w 4. Circulate hole clean with 2 bottoms up, nsure any rubber or cement is free from the hole. 5. RU N2 pumping unit. 6. Drop ball and come online with N2 and jet well dry. • Estimated volume of displaced 6% KCI is 139 bbls. If slickline or eline tags cement deeper than 9,100, Proceed with steps 7-11. 7. RIH w/ coiled tubing and jet nozzle BHA and tag PBTD. i Well Prognosis FIilcorp Alaska. I.0 Well: Kalotsa #4 Date:6/13/2017 8. PU 5ft and displace well fluids with Nitrogen. • Estimated volume of displaced 6% KCI is 139 bbl. 9. Once well is dry, verify desired surface pressure to leave on well with Operations Engineer. 10. POOH w/ coil. LD BHA. 11. RD Coiled Tubing. E -Line Procedure 12. MIRU a -line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. Note that the well is pressurized with nitrogen. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 13. Perforate the following Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns (up to 12 SPF with 2 perf runs) Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Tyonek T6B +5,349' ±5,372' ±4,172' +4,194' 23' Tyonek T10 ±5,533' ±5,547' ±4,351' ±4,364' 14' Tyonek T10B ±5,644' ±5,662' ±4,459' ±4,476' 18' Tyonek T16A ±6,343' ±6,365' ±5,142' ±5,163' 22' Tyonek T17 ±6,380' ±6,407' ±5,178' ±5,204' 27' Tyonek T17 ±6,413' ±6,437' ±5,210' ±5,234' 24' Tyonek T53 ±7,488 ±7,500' ±6,261' ±6,273' 12' Tyonek T80 ±7,984' ±7,995' ±6,745' ±6,755' il' Tyonek T115 ±8,561' ±8,597' ±7,308' ±7,344' 36' Tyonek T115 ±8,612' ±8,617' ±7,358' ±7,363' S' Tyonek T142 ±8,845' ±8,860' ±7,587' ±7,602' 15' Tyonek T146 ±9,021' ±9,084' ±7,761' ±7,823' 63' Do not commingle zone with any above a. Proposed perfs also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. Rule 2 of Conservation Order 701A defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton #1 well. The proposed bottom set of perfs (9,021'-9,084) in the Tyonek T-146 sand arelatf below the defined base of the Ninilchik Beluga/Tyonek Gas ✓ Pool (9,600' as correlated in the Paxton #1 well), see attached log. -corp Mil proposes to shoot this zone individually (no commingling) and test for J,dy reduction. If this zone proves productive, Hilcorp requests the AOGCC take ( administrative action to modify Rule 2 of CO 701A to vertically expand the defined pool to V Q 1 n�7fj'� the newly proven productive interval. If this zone proves non-productive, the interval will be plugged back before any other zones are perforated. A total of 8 wells have been drilled into or below the T-146 in this Pax -SD structure, but has not been perforated or tested in / i fig. any of thosewells /j,./ The rest of the in table above are fall within the defined Ninilchik Beluga/Tyonek Gas Pool, as currently defined. H rlil." p Al.s ., LL, 14. POOH. 15. RD e -line. Well Prognosis Well: Kalotsa #4 Date: 6/13/2017 16. Turn well over to production. (Test SSV with -in S days of stable production on well —notify AOGCC 24hrs before testing) E -line Procedure (Contingency): 1. If any zone produces sand and/or water or needs isolated 2. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 3. RIH and set 4-1/2" CIBP at depth above zone. Or 4. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Ninilchik Kalotsa #4 Correlation Log showing the 9,600' marker 2. Actual and Proposed Well Schematics 3. Coil BOPE Schematic 2-3/8" coil (Combi BOPS) and 1-3/4" coil (Quad BOPS) 4. CT Flow Diagrams (Forward and Reverse Jetting) S. Wellhead Diagram 6. Blank RWO Change Form 7. Standard Well Procedure — N2 Operations ff Ililrury Alx.ka. LLC Type RKB to GL =18' Grade 16" ID Top Btm E StY 84 X-56 6 -3/4 - 15.01" Surf Hole Surf Csg RA @ 5,490 A s L-80 RA @ 6,490' as Prod Csg 12.6 L-80 DWC/C HT 3.958" RA @ 7,500' a 0 9,213' 'T .r: 4-1/2' PBTD = 9,127'/ PBTVD = 7,865' TD = 9,221' / TVD = 7,958' CURRENT SCHEMATIC 1 CASING DETAIL Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00 Type Wt Grade Conn. ID Top Btm E StY 84 X-56 6 -3/4 - 15.01" Surf Hole Surf Csg RA @ 5,490 A s L-80 RA @ 6,490' as Prod Csg 12.6 L-80 DWC/C HT 3.958" RA @ 7,500' a 0 9,213' 'T .r: .�. RA@8,496' A ry 4-1/2' PBTD = 9,127'/ PBTVD = 7,865' TD = 9,221' / TVD = 7,958' CURRENT SCHEMATIC 1 CASING DETAIL Ninilchik Unit Kalotsa #4 PTD: 217-063 API: 50-133-20665-00 JEWELRY DETAIL No. Type Wt Grade Conn. ID Top Btm E Conductor—Driven to Set Depth 84 X-56 Weld 15.01" Surf 120' Surf Csg 29.7 L-80 Prod Csg 12.6 L-80 DWC/C HT 3.958" Surf 9,213' JEWELRY DETAIL No. Depth ID OD Item 1 1,298' 1 3.958" 1 6.875" Baker Swell Packer OPEN HOLE / CFMFNT nFTAII 7-5/8" 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/II lead and 39.5 BBLs (1815x)15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4-1/2" 6-3/4" hole. 240 bbls (675sx) 12.2 Type 1/II and 35.2 bbls (160 sx) 15.3 ppg Class G tail. 100% returns. Trace volume of spacer to surface. Est. TOC 2338' MD. Updated by CID 06-12-17 1 R'� Ls/s^ i' ID Ninilchik Unit Item 6-3/4" 1.. 3.958" PROPOSED SCHEMATIC KaloPTD: t2174063 ti ±4,172' ±4,194' 23' 6 TBD Proposed - Hilwep AImW, LLC ±5,547' 'r API: 50-133-20665-00 14' T30 TBD RKB to GL= 18' T10B ±5,644' T10B ±4,459' ±4,476' 18' CASING DETAIL TBD RA @ 5,490' A. ±6,343' ±6,365' 6" ±5,163' 4 6 TBD Size Type Wt Grade Conn. ID Top Btm TBD Proposed T16A ±6,413' i+5,•' 16" Conductor -Driven to Set Depth 84 K-56 Weld 15.01" Sufi 120' ±7,500' s!�' ±6,273' 12' T17 RA @ 6,490' L� T80 :--e ±7,995' ±6,745' ±6,755' 11' 6 TBD Proposed T315 ±9,561' 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,491' ` ±8,617' If ±7,363' RA @ 7,500' 4-1/2" Prod Csg 12.6 L-80 DWC/C HT 3.958" Surf 9,213' 77 I - Iyrtl PBTD = 9,127'/ PBTVD = 7,865' TD = 9,221'/ TVD = 7,958' 1FWFI RY DFTAII . [�l i' ID OD Item 6-3/4" 1.. 3.958" 6.875" eaker5well Packer Hole ti ±4,172' ±4,194' 23' 6 TBD Proposed - T68 ±5,547' 'r ±4,364' 14' T30 TBD Proposed T10B ±5,644' T10B ±4,459' ±4,476' 18' 6 TBD RA @ 5,490' i- ±6,343' ±6,365' ±5,142' ±5,163' 4 6 TBD Proposed T17 ±6,380' ±6,407' t ±5,204' 27' 6 TBD Proposed T16A ±6,413' i+5,•' ±5,210' ±5,234' T17 6 �r, c Proposed T53 ±7,988, ±7,500' s!�' ±6,273' 12' T17 RA @ 6,490' L� T80 :--e ±7,995' ±6,745' ±6,755' 11' 6 TBD Proposed T315 ±9,561' ±8,597' ±7,308' ±7,344' 36' 6 - T53 T115 28,612' ±8,617' If ±7,363' RA @ 7,500' 6 TBD Proposed T142 ±g,gg5 ±8,860' ±7,587' ±7,602' 15' 6 TBD Proposed T346 T80 ±9,084' ±7,761' ±7,823' 63' 6 TBD -* RA @ 81496' T115 T115 ` T142 T146 PBTD = 9,127'/ PBTVD = 7,865' TD = 9,221'/ TVD = 7,958' 1FWFI RY DFTAII . [�l Depth ID OD Item Amt 1,298' 3.958" 6.875" eaker5well Packer PIPPMRATIM14Z Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status T68 ±5,349' ±5,372' ±4,172' ±4,194' 23' 6 TBD Proposed TO ±5,533' ±5,547' ±4,351' ±4,364' 14' 6 TBD Proposed T10B ±5,644' ±5,662' ±4,459' ±4,476' 18' 6 TBD Proposed T16A ±6,343' ±6,365' ±5,142' ±5,163' 22' 6 TBD Proposed T17 ±6,380' ±6,407' ±5,178' ±5,204' 27' 6 TBD Proposed TV ±6,413' ±6,437' ±5,210' ±5,234' 24' 6 TBD Proposed T53 ±7,988, ±7,500' ±6,261' ±6,273' 12' 6 TBD Proposed T80 ±7ggq• ±7,995' ±6,745' ±6,755' 11' 6 TBD Proposed T315 ±9,561' ±8,597' ±7,308' ±7,344' 36' 6 TBD Proposed T115 28,612' ±8,617' ±7,358' ±7,363' S' 6 TBD Proposed T142 ±g,gg5 ±8,860' ±7,587' ±7,602' 15' 6 TBD Proposed T346 29,021' ±9,084' ±7,761' ±7,823' 63' 6 TBD Proposed OPEN HOLE / CFMFNT nFTAll 7-5/811 9-7/8" hole. 100 BBL (226 sx) of 12 ppg Type 1/II lead and 39.5 BBLs (181sx) 15.4 ppg Class G tail. 100% returns throughout, 51 bbls of lead to surface. 5/14/17 4-1/2° 6-3/4" hole. 240 bbls (6755x) 12.2 Type 1/11 and 35.2 bbis (160 sx) 15.3 ppg Class G tail. 300% returns. Trace volume of spacer to surface. Est. TOC ±3381 MD. Updated by DMA 06-12-17 Z' 1502 H Flaig (M: 2-1116 10K 9 (h Ninilchik Unit Kalotsa 4 06/12/2017 Coiled Tubing HR580 Injector Head & Gooseneck Weight =12,850 lbs 4-1116" 10K Conventional Stripper SK C062 Wbriwtor 5K C062 x 4.1116" 10K Flange 4-1116" SOK ComBOP Top Set: Blirxl/Sheaear Secmd Sel: Pipe/Slp 4-1116" 10K Flow Cross Manual 2x2 Valve 1: T' 1562 x 2-1/16" 10K Rarge Manua' 2x2 Valve 2: 2-0/16" 10K x 2-1/16" 10K Range Manua 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Rarge Mmuel 2x2 Valve 4: 2" 1502 x2-1/16" 10K Flange 4.1116" 10K x Wellhead Adapter Flange Wellhead a oUnit Kalotsatsa 3&4 naM .�u .►., �.ta: 06/12/2017 Coil Tubing BOP Lubricator to injection head 1.75" Tandem Stripper Blind/Shear--�r 1/16 10' rBlind/Shear Blind/Shear W�Jm��°Mud Cross � E Awa■i Outlet opening FMC valves log JF,7 m6law Manual Manual Manual Manual 21/1610M 21/1610M 21/1610M 21/1610M Crossover spool 4 1/16 10M X 4 1/16 5M Q Q Z5 I Ll Z Nini thik unit Worse #1 and 2 16x75/8 x4% BH A, Otis, 411165M FE x 6.5 Otis quick union top Valve, Upper marteq WKM-M, 41/16 SM FE, HWO, EE trim Tubing head, Cactus C-291.- HP5, 135/8 SM x 115M, w/ 2- 21/16 SM 550 Starting head, Cactus C -29L, 135/85M x 16 SOW, w/ 2-2 1/165M 550 Kalots ik Unit I{alotsa #3 and #4 06/12/2017 C.eN hanger, CW, 11 x 4 % DWC/C box btm x 6.125" RH Mb acme box top, w/ 7 5/8 od neck, 4" type H BPV profile, DD -NL material Valve, Wing, 55V, WKM-M, 31/8 SM FE, w/15" Hydraulic operator UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well Kalotsa #4 (PTD 217-063) (API 50-133-20665-00) Sundry #:217 -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date STANDARD WELL PROCEDURE llilcorp Alaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 ADDITIONAL TEXT FOR APPROVAL LETTER Kalotsa 4 - Planned Perforations Sundry #317-253 PTD #217-063 Planned perforations in the T146 sand interval (T146) will lie below the base of the Ninilchik Beluga/Tyonek Gas Pool as defined in Conservation Order No. 701A. Per Regulation 20 AAC 25.215, commingling of production from two or more pools is prohibited without an order from the AOGCC. Should testing of the T146 prove successful, expansion of the Ninilchik Beluga/Tyonek Gas Pool to include the T146 under Rule 6 of Conservation Order No. 701A requires a proper application from Hilcorp that justifies expansion of the pool based on sound engineering and geosciences principles. P7b ZI70(,30 Regg, James B (DOA) From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Tuesday, May 30, 2017 6:05 AM e l c5InP1-7� To: Regg, James B (DOA) ��( Cc: Laubenstein, Lou (DOA) Subject: Notice of BOP Closure, SLR 169 Attachments: SLB 169 Notice of BOP Use.docx Jim, we made a BOP closure last night while circulating out gas. Please see the attached closure notice. Lou, we are just starting to pull out of hole from 9221'. Will be approximately 9 hours trip time. I will update you again in a couple hours for a better test time this afternoon/early evening. I'll be in the doghouse during the trip, feel free to call my cell any time. Rance Pederson Drilling Foreman Ninilchik Unit 907-776-6776 office 907-398-4847 cell .n ❑IL.np LI I Notice of BOP Use • Date/Time: 5/29/2017 at 22:40 hrs. • Well: Kalotsa #4 • Location: Ninilchik Unit, Kalotsa Pad, Mile 129.75 Sterling Hwy • PTD: 217-063 • Rig Name: SLR 169 Schlumberger • Operator Contact: Rance Pederson at 907-776-6776 / rpederson@hilcorp.com • Operation Summary: 6 %" production hole drilled to 9221' md. Current mud weight 9.4 ppg, background gas was 21 units. While making cleanout run, washing & reaming to TD, bit depth was 8629. Observed background gas starting to increase. Decision was made to circulate bottoms up prior to continuing in hole. Max gas seen on Pason was 2384 units and trending down. With gas at approximately 1100 units, observed flow increase, gas breaking out at surface and fluid erupting above rotary table. Driller and tour pusher shut in well @ 22:40 hrs. • BOPE Used: Upper 4.5" rams and auto choke valve. • Reason For BOPE Use: Had drilling mud erupt through rotary table, flow show increased from 20% to 50% in a matter of seconds and a 4 bbl pit gain. • Actions Taken: Monitored SICP and SIDPP, SICP initial 84 & final 212 psi, leveled out in 30 min. SIDPP = 0. Lined up and circulated one full circ through choke and poor boy d !gasser vessel to circ out gas. After one full circ at slow pump rate, checked for flow and had no flow. Opened well and circulated to 9.5 ppg mud. After flow check, continued to trip in hole to bottom. THE STATE °fALASKA GOVERNOR BILL WALKER Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Kalotsa 4 Hilcorp Alaska, LLC Permit to Drill Number: 217-063 Surface Location: 2281' FSL, 481' FWL, SEC. 7, TIS, R13W, SM, AK Bottomhole Location: 2447' FNL, 2166' FWL, SEC. 12, TIS, R14W, SM, AK Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. DATED thi<da of May, 2017. Sincerely, �a/ Cathy . Foersteri Chair nGVG1 r L -v STATE OF ALASKA APR 2 1 2017 AL A OIL AND GAS CONSERVATION COMM1, ON PERMIT TO DRILL A(7G�C� 9n AAC I)a nn'; 1a. Type of Work: Drill ❑� • Lateral ❑ Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas Service- WAG LJ Service - Disp L]1c. Stratigraphic Test ❑ Development - Oil ❑ Service- Winj ❑ Single Zone ❑� ' Exploratory - Oil ❑ Development -Gas Service - Supply ❑ Multiple Zone ❑ Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 Kalotsa 4 - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 8,922' • TVD: 7,661' • Ninilchik Field Beluga/fyonek Gas Pool 4a. Location of Well (Governments] Section): 7. Property Designation (Lease Number): Surface: 2281' FSL, 481' FWL, Sec 7, TIS, R13W, SM, AK • C061505 (SHL) / ADL384372 (TPH/BHL) Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2386' FNL, 2463' FWL, Sec 12, T1S, R14W, SM, AK Total Depth: 2447' FNL, 2166' FWL, Sec 12, T1 S, R14W, SM, AK N/A 5/25/2017 9. Acres in Property: C061505 1615 acres / ADL384372 3147 acres 14. Distance to Nearest Property: 6,097' to nearest unit boundary 4b. Location of Well (Slate Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 144.5 ' 15. Distance to Nearest Well Open Surface: x-209881 y- 2233554 • Zone -4 GL Elevation above MSL (ft): 126.5. to Same Pool: 525' Paxton 7 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 53 degrees Downhole: 3447 - Surface: 2681 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 120' Surface Surface 120' 120' Driven 9-7/8' 7-5/8" 29.7# L-80 BTC 1,500' Surface Surface 1,500' 1,395' L -506.4113/T-182 ft3 6-3/4" 4-1/2" 12.6# L-80 DWC/C HT 8,922' Surface Surface 8,922' 7,661' 1486 ft3 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (11): 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 Q BOP Sketch Q Drilling Program Q Time v. Depth Plot ❑✓ Shallow Hazard Analysis ❑ Divener Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑� 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Monty Myers Email mm erS hilcor .COM Printed Name Paul Mazzolim Title Drilling Manager Signature ?a..P— _ Phone 777-8369 Date 4/21/2017 Commission Use Only Permit to Drill% Number: 7—a API Number: 54 Permit Approval Date: f2l 0i 11-7 See cover letter for other 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: Other: c' ;j '�� r -y 3 CIL)()PS UU 6 I C S,1�� ,�uSamples req'd: Yes ❑ No Mud log req'd: Yes r❑-� No u r �� r-�-Qy- wru t! L� 0✓' ZO (v r- 25.435 �h��`•�zS measures: Yes ❑ No r�f Directional svy req'd: Yes Uv No❑, Spacing exception req'd: Yes ❑ N,5 Inclination -only svy req'd: Yes ❑ Nog k C 13 IIIA I T- IA {b 2-56D ps, Post initial injection MIT req'd: Yes ❑ No ❑ d APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /_r ��~� r 1 • Submit Fomi and ` Fo 1 (Revised 11/2015) 0 RIp@rr�riNiA14 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate V IVHL �4�/ ,� L)_16 (-? H Hilcorp eon comer UpAr` SI Monty Myers Drilling Engineer Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Kalotsa 4 Dear Commissioner, Enclosed for your review is the application for permit to drill Kalotsa #4. Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com RECEIVED APR 2 12017 AOGCC Kalotsa #4 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 500' MD. Maximum hole angle will be 53 deg. and TD of the well will be 8922' TMD/ 7661' TVD, ending with 12 deg inclination left in the hole. Vertical section will be 3613 ft. 5LR Drilling operations are expected to commence approximately May 251h 2017. The Saxon Rig # 169 will be used to drill the wellbore then run casing and cement. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, FoyerMonty M ers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC Kalotsa #4 Drilling Program Ninilchik Unit Rev 0 April 20th, 2017 Kalotsa #4 Hilc01'p Drilling Procedure E.n 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...............................................................................................................13 12.0 Run 7-5/8" Surface Casing...........................................................................................................17 13.0 Cement 7-5/8" Surface Casing.....................................................................................................19 14.0 BOP NIU 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 (wp06)................................................................................................................47 U Hileorp e� cm,�, 1.0 Well Summary Kalotsa #4 Drilling Procedure Rev 0 Well Kalotsa #4 ' Pad & Old Well Designation Kalotsa #4 is a grass'roots well on Kalotsa Pad Planned Completion Type 4-1/2" Production tubing Target Reservoir(s) Belu a/T onek • Planned Well TD, MD / TVD 8,922 MD / 7,661' TVD PBTD, MD / TVD 8,800' MD / 7,542' TVD Surface Location (Governmental) 2281' FSL, 481' FWL, Sec 7, TIS, R13 W, SM, AK Surface Location (NAD 27) X=209881.34, Y=2233554.05 Surface Location (NAD 83) Top of Productive Horizon (Governmental) 2386' FNL, 2463' FWL, Sec 12, TIS, R14W, SM, AK TPH Location (NAD 27) X=206599.7, Y=2234161.08 TPH Location (NAD 83) BHL (Governmental) 2447' FNL, 2166' FWL, See 12, T1 S, R14W, SM, AK BHL (NAD 27) X=206301.46, Y=2234107.79 BHL AD 83) AFE Number 1710633D AFE Drilling Das 4 MOB, 18 DRLG AFE Completion Days AFE Drilling Amount $3,143,072 AFE Completion Amount $400,000 Maximum Anticipated Pressure (Surface) IMSP 2681 psi Maximum Anticipated Pressure (Downhole/Reservoir) 3447 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 April, 2017 2.0 Management of Change Information Kalotsa #4 Drilling Procedure Rev 0 El Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: April 20, 2017 Subject: Changes to Approved Permit to Drill for Kalotsa #4 File #: Kalotsa #4 Drilling Program Any modifications to Kalotsa #4 Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Approval: Manager PreparedMonty M Myers Drilling Engineer Date Page 3 Version 0 April, 2017 3.0 Tubular Program: Kalotsa #4 Drilling Procedure Rev 0 Hole ction Cond OD On) ... 16" H) On) 15.01" Drift 14.822 Conn in 17" Wt #/ft 84 Grade J-55 Conn Weld Burst 2980. Collapse Tension 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-U2" 3.958" 3.833" 5.0" 12.6 L-80 Dwac HT 8430 7500 288 4.0 Drill Pipe Information: All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 April, 2017 Collapse -. n si k -lbs All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 April, 2017 n Hilcorp 5.0 Internal Reporting Requirements Kalotsa #4 Drilling Procedure Rev 0 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to omazzolini@hilcom.com, mmyers@hilcoEp.com and edinger@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: O: (907) 777-6726 C: (907) 227-3189 b. Matt Hogge: O: (907) 777-8418 C: (907) 227-9829 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 • Notify Drlg Manager 1. Paul Mazzolini: O: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers@hilcorp.com and cdingerahilcoro.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcoLp.com and cdinger@hilcoa2.com Page 5 Version 0 April, 2017 Kalotsa #4 Drilling Procedure Rev 0 Hilcorp Enema Company 6.0 Planned Wellbore Schematic 16' 7-5+s 6-314 Hol 4-1 n PMD=8,8•t2' 7PIM-D=7-a' 1D= 8.922' ! TCD= 7,661' PROPOSED ------------- CASING DETAIL Ninilchik Well Kalotsa #4 PTD: 000-000 AFI: 50-000-00000-00 Size Type WtGad. Conn. ID Top Btm Mud Weight Conductor —Driven 16" to Set 84 X-56 Weld 1501" Surf 120' N/A Depth 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 1,500'. 8-8 ppg 4-1,12" Prod Csg 12.6 L-80 D HT/C 3.958" Surt 8,922'. 9-5 ppg frT� - - Drilling Info Fide Section Casing IVTW 49orkstring 9-7/8" 7-5/8" 8.8 ppg A -1/2- &S/4" 1/2-6-3 4" 4-2/2" 92-10.5 ppg 4-1/2- ----------------------- ------------------------------------------------------------------- i JEWELRY 1 2" ---'---------'--------"'----------'----------------------------------------------------- JEWELP.V DETAIL Na Depth ID OD Item 1 1,300' 3.958" 6.875" Baker Swell Packer Paae 6 Version 0 April, 2017 7.0 Drilling / Completion Summary Kalotsa #4 Drilling Procedure Rev 0 Kalotsa 44 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 500' MD. Maximum hole angle will be 53 deg. and TD of the well will be 8922' TMD/ 7661' TVD, ending with 12 deg inclination left in the hole. Vertical section will be 3613 ft. Drilling operations are expected to commence approximately May 25a 2017. The Saxon Rig # 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 1,500 MD / 1,395' 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 Kertat'5—asTi—eld- G&I facility for disposal / beneficial reuse depending on test results. General sequence of operations: SLR 1. MOB Saxon Rig # 169 to well site 2. N/U conductor riser. (No diverter, diverter waiver requested) aK 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 8,922' MD. Perform Wiper trip. 6. Make cleanout run 7. POOH laying down drill pipe. 8. Run and cmt 4-1/2" production casing. 9. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR + Res 2. Production Hole: GR + Res + Den/Neu (LWD). 3. Mud loggers from surface casing point to TD. Page 7 Version 0 April, 2017 U �11C Kalotsa #4 Drilling Procedure Rev 0 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling of Kalotsa #4. Ensure to provide AOGCC 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/10 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Regulation Variance Requests: Diverter waiver requested due to the recent drilling of Kalotsa #1 and Kalotsa #2 nearby (-50' away). No issues were experienced while drilling the surface hole. Surface casing for these wells were set at 1500' TVD. Surface casing is requested to beset at 1,395' TVD on Kalotsa #4. No shallow hydrocarbon zones will be penetrated. W6, 7,1er ,t��ro"a'/ 'Pc' 5 e r-.. rn1 `7 U 71�- �1-17--i7- Page 8 Version 0 April, 2017 U Hilcorp E• Camps" Summary of BOP Equipment and Test Requirements Kalotsa #4 Drilling Procedure Rev 0 Hole Section Equipment Test Pressure(psi) 9-7/8" • No diverter utilized n/a • 11" x 5M Townsend Annular BOP • I l" x 5M Townsend Double Ram Initial Test: 250/3500 o Blind ram in bum 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: iim.regggalaska. ov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guv.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors dalaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/oec/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Version 0 April, 2017 H Hilcorp En W comp., 9.0 R/U and Preparatory Work Kalotsa #4 Drilling Procedure Rev 0 9.1 Set 16" conductor at +/-120' below ground level. 9.2 Dig out and set impermeable cellar.Pi' tj,44 4,10 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig # 169, spot service company shacks, spot & R/U company man & toolpusher offices. 9.7 RU Mud loggers on surface hole section for gas detection only. No samples required 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 9-7/8" hole section. 9.10 Install 5-1/2" liners in mud pumps. • HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 strokes with 5-1/2" liners. Page 10 Version 0 April, 2017 a Drillinging Procedure dure 11 Rev 0 Hi COTe Ena Company 10.0 NIU 16" Conductor Riser 10.1 NIU 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 April, 2017 U Hilcorp Endep C pa 103 Rig Orientation on Kalotsa pad: Kalotsa #4 Drilling Procedure Rev 0 Page 12 Version 0 April, 2017 U Hilcorp F -W Company 11.0 Drill 9-7/8" Hole Section Kalotsa #4 Drilling Procedure Rev 0 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 Res are included in below BHA): I COMPONENTD Item # 1 Description Serial Number 9-718' PDC .r 6.020 2.250 ht M[bpo 9.875 83.45 Top connection P 4-112" REG Length 00 0.89 Cumulative Length (11) 0.69 2 7" SperryDnll Lobe 718 - 7-5 stg 7.000 4.952 95.69 B4 -1,71F 30.00 30.89 Stabilizer 9.625 3 6-3/4" Integral Blade 9 14" 6.760 2.500 9.750 105.59 8 4-112" IF 6.99 37.88 4 6-3/4" Float Sub 6.800 2.375 108.67 B 4-112" IF 3.00 40.88 5 6314" DM Collar (Directional) 6.720 3.125 103.40 B 4-1/2" IF 9.20 50.08 6 6 314" DGR Collar (Gamma) 6-710 1.920 97.80 B 4-112" IF 6.50 56.58 7 6 314" EWA-P4 Collar (Resistivity) • 6.710 2000. 104.30 B 4-112" IF 12.00 68.58 8 6 3/4" PWD Collar (Pressure) 6.720 1.905 96.3D B4 -101F 4.44 73.02 9 6 3,14" HCIM Ca➢ar (Processor) 6.750 1.920 10170 B 4-112" IF 6-50 79.52 1 D 6 3r4" TM Collar (Telemetry) 6.550 3.250 103.60 B 4-112" IF 9.90 89.42 11 675" NM Flex Collar 6.450 2.875 8923 B 4-112" IF 30.00 119.42 19 X -Over Sub 4-112 IF x CDS 40 6.450 2.625 92-91 B 4_ CDS 40 3.00 122.42 3As4-1/2"HWDP 4.500 2.813 36.86 1 93.00 215.42 1: X -Over Sub CDS 40 x 4-112 IF 6.300 2.625 87.79 B 4-112" IF 3.00 218.42 15 6-1/4" Weatherford Jar 6270 2250 91.68 B 4-112" IF 30.00 248.42 16 X -Over Sub 4 -IQ IF x CDS 40 6.230 2.625 85-44 B 4.5" CDS40 3.00 251.42 - 51ts 4-1/2" HWDP 4.500 2.813 36.86 155.00 406A2 406-42 Page 13 Version 0 April, 2017 a Drillinging Procedure dure Rev 0 Hileorp Enegy Cmnpwy 11.3 Primary Bit: PRODUCT SPECIFICATIONS Cutkr Typo Selcetcunct IADC Cale M323 Body Type MATRIX 7aNal ('utler('nunl 46 Cuncr Distribution I min I= Faw (l 20 Gauge 12 0 Up Mill 6 0 Number of Large Noales 6 Number of 3ledium Nmks 0 NumberafSaudi Nozzles 6 Number of Micro NmIcs 6 Nunlbsv ofPortz(%i -) 0 NumberofRaplaccablc Ports (Sin) 0 Junk Sla Area Iso in) 16.71 N.M.hnd Fan: Volume 45.49'5: API Connection 4-112 REG. PIN Reconvmca" Make-up Torque' 1-461 - 17,766 R-16. Nominal Dimensions'• ilnk -Up Face to Nose 10.81 in - 275 nm 0.1'ge Length 2.5 in .64 tmn Sleeve Length 0 in - 0 mm Shan: Diameter 6 in - 152 turn Break Out Plate (Mat,M LcgaryUl 101954+44040 Apiamilnate Shipping Weight 2501bs.-113Kg. SPECIAL FEATURES Up -Drill Cutters on ciagc Pads. 116- Relieved Gage Material #771827 'Bit specific rcmmmendcd mato-., mrquc k : (..snortof du bit LD. and aa.1 hit sub D.D. W ili. A. srvaF.d in API RP7G Section AR2. •Vleugnd........ um..niwl rmi......ry lightly rre an. Hullihao. Drill Has adScnicn nuxlelaare mminmsu'ly rcsa cd and rc6r�. Product specifxuiwu.0 abanirc-ift., n aicc. 02013 Halliburton. All rights reserved_ Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the coni t between Halliburton and the corner that is applicable to the sale. Page 14 Version 0 April, 2017 n Hileorp Ev C2,T Kolotso #4 Drilling Procedure Rev 0 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 9-7/8" hole section to 1,500' MD/ 1,395' 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 DensityViscosityPlastic Viscosi Yield Point API FL H 120-1500' 8.8 — 9.5 85-150 20-40 1 25-45 1 <10 1 8.5-9.0 ��J Page 15 Version 0 April, 2017 n Hilcorp System Formulation: Aquagel + FW spud mud Product FRESH WATER SODA ASH AQUAGEL CAUSTIC SODA BARAZAN D+ BAROID 41 PAC -L /DEXTRID LT ALDACIDE G X -TEND II Concentration 0.905 bbl 0.5 ppb 12-15 ppb 0.1 ppb (9 pH) as needed as required for weight if required for <12 FL 0.1 ppb 0.02 ppb Kalotsa #4 Drilling Procedure Rev 0 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. Page 16 Version 0 April, 2017 H Hib Campaoy orp Env 12.0 Run 7-5/8" Surface Casing 12.1 R/U and pull wearbushing. Kalotsa #4 Drilling Procedure Rev 0 12.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill -up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. Keep hole covered while R/U casing tools. Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end & thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 7-5/8" surface casing ✓ • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 7,630 ft -lbs Page 17 Version 0 April, 2017 Kalotsa #4 Drilling Procedure Rev 0 Hi1COrp Ena comp y 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 LBO Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 Ibs 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 PIU casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 18 Version 0 April, 2017 13.0 Cement 7-5/8" Surface Casing Kalotsa #4 Drilling Procedure Rev 0 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the curt 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 BLS Vol ft3 12.0 ppg LEAD: 120' x .0932 bpf = 11.2 63 16" Conductor x 7-5/8" casing annulus: 12.0 ppg LEAD: (1500' —120') x .0382 bpf x 79 444 9-7/8" OH x 7-5/8" Casing 1.5 = annulus: Total LEAD: 1.46 Fr 90.2 506.4 ft3 15.4 ppg TAIL: (1500'-1000') x .0382 bpf x 28.7 161 9-7/8" OH x 7-5/8" Casing 1.5 = annulus: 15.4 ppg TAIL: 80 x .04591 bpf = 3.7 21 7-5/8" Shoe track: Total TAIL: 1 34.2 bbl 182 ft3 Page 19 Version 0 April, 2017 205 -1& 14`I sx U Hilcorp Energy ComP�Y Cement Slurry Design: Kalotsa #4 Drilling Procedure Rev 0 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace curt 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 April, 2017 Lead Slurry (1000' MD to surface) Tail Slurry (1000'to 1500' MD) System Extended Conventional Density 12 Ib/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 5002 CaC12 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaC12 0.1 % BWOC 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace curt 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 April, 2017 H E1COrpprw Kalotsa #4 Drilling Procedure Rev 0 13.13 Do not overdisplace by more than''/2 shoe track volume. Total volume in shoe track is 3.7 bbls. P_� 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 successor problems during the cement job Send final "As -Run " casing tally & casing and cement report to cdinjzer@hilcorp.com and mmvers2hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 21 Version 0 April, 2017 H Hilcrp E.c ,2, 14.0 BOP N/U and Test Kalotsa #4 Drilling Procedure Rev 0 14.1 N/U Seaboard multi -bowl wellhead assy. Install 7-5/8" packoff P -seals. Test to 3000 psi. 14.2 N/U 11" x 5M Townsend BOP as follows: • BOP configuration from Top down: 11" x 5M Townsend Type 90 annular BOP/11" x 5M Townsend Model 82 double ram /11" x 5M mud cross/11" x 5M Townsend Type 82 single ram • Double ram should be dressed with 4-1/2" solid body rams in top cavity, blind ram in btm cavity. • Single ram should be dressed with 4-1/2" solid body rams • N/U bell nipple, install flowline. • Install (2) manual valves & a check valve on kill side of mud cross. • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.3 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/10 min. Test annular to 250/2500 psi for 5/10 min. O� • Ensure to leave `B" section side outlet valves open during BOP testing so pressure does not tyk 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 April, 2017 n 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. Kalotsa #4 Drilling Procedure Rev 0 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray and Resistivity LWD functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.7 Workstring will be 4.5" 16.69 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 April, 2017 ff Hilcorp Eo Company 15.8 6-3/4" BHA: Kalotsa #4 Drilling Procedure Rev 0 428.84 Page 24 Version 0 April, 2017 1 HDBS MMD84 4.750 1.500 1 6.750 54.37 P 3112" REG 0.80 0'80 2 4 3t4' SperryDril Lobe 5'6. 8.3 sig 4.750 2.794 44.57 B 312" IF 26.70 27.50 Stabilizer 6.375 3 4 3'4- NM Integral Blade Stabilizer 4,750 2.313 6.500 46.07 8 3.1,2" IF 5.60 33.10 4 4 3'4' DM Collar (Directional) • 4.750 2.610 47.00 B 3-1/2' IF 9.18 4228 5 4 3'4' PND 25KSI (Pressure) 4.750 1250 47.90 8 NC 38 9.23 51.51 6 Wine Stabilizer (ILS) 4.750 1.250 6.500 56.21 B 3-112' IF 3.00 54.51 7 4 34' SP4 (Resiswity Gamma) • 4.750 1,250 48.20 B NC 38 22.50 77.02 8 Inline Stabiizer (ILS) 4.750 1250 6.500 56.21 B 3-112" IF 3.00 80.02 9 4 314' ALD Collar (Density) 4.750 1.250 6.375 45.50 B NC 38 14.35 94.37 Stebii¢er 6.375 10 4 314' CTN CoUr (Porosity) 4.750 1.250 50.50 B NC 38 11.14 105.51 11 4 3'4" TM Collar (Telemetry) 4.750 2.812 46.10 B NC 38 10.86 116.37 12 4-3'4' NM Flex 4.750 2.313 46.07 8 312" IF 30.00 146.37 13 a 3'4' NM Flex 4.750 2.313 46.07 B 312" IF 30.00 176.37 14 4 3'4' NM Flex 4.750 2.313 1 46.07 B 3112' IF 30.00 206.37 15 4 3'4' Foal Sub 4.750 2.250 46.84 6 3.12" IF 2.50 208.87 16 4 112' IF P to XT. 39 8 XO Sub 4.750 2.500 43.66 8 4• XT39 1.67 210.54 17 1 it 4' HW DP XT -39 4.OD0 2.563 25.24 31.50 242.04 18 4 3r4- Hydraulic Jar 4.635 2250 43.95 8 4' X739 29.30 271.34 19 4 its 4' HW DP XT -39 4.000 2.563 2524 126.00 397.34 20 4' DP XT -39 4.000 3.240 14.73 31.50 428.80 428.84 Page 24 Version 0 April, 2017 H Hilcorp 15.9 Primary Bit: PRODUCT SPECIFICATIONS Cutler Tyle let - Eztrcrne Dulling IADC Code M323 Body Type MATRIX Total Cutter Caunt 13 Curter Disttibution 1:OII7h I(Nnm Face 4 13 Gauge I I 9 Up Drill 3 0 Number of Large Nozzles 0 Number of Medium Nozzles 6 Number of Small Nozzles a Number of Micro Nooks 0 Number of Puna (Sia) a Numborof Replaceable Ports tSire) 0 Junk Sim Area (sq in) 8.69 Nnnnalved Face. volume 341.69"i API Connection 34U2 REG. PIN Reeotmnetsdd Makc-Up Turquc• 3.173- 7,663 Ft -lb;. Nominal Dimensions•• Make -Up Face to Nose 11.42 in -239 an Guugc Length 2 in - SI mm Sleeve Length 0 in - 0 mm Shank Diameter 45 in - 114 nam Drcak Out Phnc (Ma1.N4 xga y41 18195344030 Approximate Shipping Weight 901-b&-41 Kg, SPECIAL FEATURES Up -Drill C utterson Gage Pads, V l6" Slcpped Qi;c. 0immired Dual Row - "D" Feature Kalotsa #4 Drilling Procedure Rev 0 Material #761302 'Bit tperific tectomnrndcd make-up "uv i> a function of the bit I.D. and aclml hit sub O.O. miliml m>pcired in AN RP% Section A.R.2. "&sign dimensinns>n �iud and arty cap slightly on nwaabound product. naltihunan Drill Rio and Scniax ..-&h me caa in".1y rcssv.ed ani tefuw,d. PkAuct ep,:eltiradeni may ehznae kiukmt 1.0640. ?:: 2013 Halhburlon. All rights reserved. Sales of Hnllibmton products and services will he in aecord solely with the terms and conditions contained in the contract between Halliburton and the enslomer that is applicable to the sale. Page 25 Version 0 April, 2017 H Hi1C0rp a—V c®wor 15.10 6-3/4" hole section mud program summary: Kalotsa #4 Drilling Procedure Rev 0 Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: System Formulation: 6% KCL EZ Mud DP Product Mud dViscosity Water Plastic KCI 22 ppb (29 K chlorides) Caustic MD BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP Yield Point pH HPHT PAC -L Weight1,500'- BARACARB 5/25/50 ty BAROID 41 as required for a 9.0 —10.0 ppg ALDACIDE G 8,922' 9.0-10.0 , 40-53 1 15-25 1 15-25 1 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 /AM report. B 15.12 R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT grap 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 April, 2017 U HilcOrp E.n C2jx 15.15 Conduct FIT to 13.5 ppg EMW. Kalotso #4 Drilling Procedure Rev 0 Note: Offset field test data predicts frac gradient at the 7-5/8" shoe to be between 11 -13 ppg EMW. A 13.5 ppg FIT results in a 4 ppg kick margin while drilling with the planned MW of 9.5 PPS• F/mak (✓ Kick tolerance= (13.5-9.5)X(1395/7661) = 0.7373 15.16 Drill 6-3/4" hole section to 8,922' MD / 7,661' TVD • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 225 - 300 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every 100' drilled. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. 15.17 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 15.18 TOH with the drilling assy, standing back drill pipe. 15.19 LD BHA, RU E -line to perform RFT logging and sidewall coring. 15.20 RD loggers, PU 6-3/4"clean out BHA, and TIH to TD. 15.21 Pump sweep, CBU and condition mud for casing run. 15.22 POOH LDDP and BHA 15.23 4-1/2" pipe rams previously installed in BOP stack and tested. Page 27 Version 0 April, 2017 0 Hilcorp EncW Company 16.0 Run 4-1/2" Production Casing Kalotsa #4 Drilling Procedure Rev 0 16.1. R/U Weatherford 4-1/2" casing running equipment. • Ensure 4-1/2" DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue MfU & 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 MX 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 April, 2017 n Hileorp En a C22 Technical Specifications Kalotso #4 Drilling Procedure Rev 0 Connection Type: Size(O.D.): Weight (Wall): DWC/C Tubing 4-1/2 in 12.60 Ibtft (0.271 in) standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) 95,000 Minimum Ultimate Strength (psi) Pipe Dimensions 4.500 Nominal Pipe Body O.D. (in) 3.958 Nominal Pipe Body I.D.(in) 0.271 Nominal Wall Thickness (in) 12.60 Nominal Weight (lbslft) 12.25 Plain End Weight (lbstft) 3.600 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (Ibs) 7,500 Minimum Collapse Pressure (psi) 8,430 Minimum Internal Yield Pressure (psi) 7,700 Hydrostatic Test Pressure (psi) Grade: L-80 VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713479-3200 Fax 713479-3234 E-mail: VAMUSAsales®vam�.wm Page 29 Version 0 April, 2017 Connection Dimensions 5.000 Connection O.D. (in) 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter (in) 3.94 Make-up Loss (in) 3.600 Critical Area (sq in) 100.0 Joint Efficiency (%) Grade: L-80 VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713479-3200 Fax 713479-3234 E-mail: VAMUSAsales®vam�.wm Page 29 Version 0 April, 2017 Connection Performance Properties 288,000 Joint Strength (Ibs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (Ibs) 288,000 Compression Rating (Ibs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-Ibs) 6,500 Maximum Final Torque (ft-Ibs) 7,200 Connection Yield Torque (ft-Ibs) Grade: L-80 VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston, TX 77041 Phone: 713479-3200 Fax 713479-3234 E-mail: VAMUSAsales®vam�.wm Page 29 Version 0 April, 2017 H Hilcorp Enc�gy Compmy Kalotsa #4 Drilling Procedure Rev 0 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 30 Version 0 April, 2017 U Hileorp 6ne`gy Ca pzny 17.0 Cement 4-1/2" Production Casing Kalotso #4 Drilling Procedure Rev 0 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • Pump 20 bbls of freshwater through all of Schlumberger's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement 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. kd. Z I cj' 6AC-s Section: Calculation: Vol lVol (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: (8922 — 1500) x 0.025 x 1.35 = 250 1404 Shoe Track: 80' x 0.019 = 1.5 8.5 Total Volume: 264.5 1486 Page 31 Version 0 April, 2017 U Hilcorp e� 17.7. Drop wiper plug and displace with 6% KCI. Kalotsa #4 Drilling Procedure Rev 0 17.8. If hole conditions allow — continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 2- da' .01`(rj X 0"",= 13 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 % 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. k �t1 z 17.14. WOC minimum of 12 hours, test casing to 3500 psi and chart for 30 minutes. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the successor problems during the cement job Send final "As -Run" casing tally & casing and cement report to mmversAhilcorp com This will be included with the EOW documentation that goes to the AOGCC Page 32 Version 0 April, 2017 H H11Ce O�Tp 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 C6 Kalotsa #4 Drilling Procedure Rev 0 M l T- IA a ZSDo r s� Page 33 Version 0 April, 2017 U Hilcrp Fm 121-y 19.0 BOP Schematic Kalotsa #4 Drilling Procedure Rev 0 Ide Page 34 Version 0 April, 2017 Grade H Hilcorp Enmgy Company 20.0 Wellhead Schematic 300%MaA( HIS. 135/85N 221/16 Slad"Ith" A( 135/85M a 116 1/161 Ninamik unit "o. 61 aM 2 16.35/8 v AA 8Kq O[B, 01/I65M R a 65 Otis Quitk uNu top Kalotsa #4 Drilling Procedure Rev 0 C 1.1-1.1,M 11 aov OWC/C Yabnna6135"RM ". aame boy I.P. w/ 35/8 N nttk A" tlpe M M pmllM, X) MI matceial Page 35 Version 0 April, 2017 Kalolsa Drilling Procedure Hilcorp Rev o �� cz 21.0 Days Vs Depth 100 200( 300c 02 F. r n a v 5000 m m v .�50. mm #I 9000 Days Vs Depth 0 5 10 15 20 25 30 Days Page 36 Version 0 April, 2017 Kalotsa Drilling Procedure Rev 0 Hilcorp Enngy Company 22.0 Geo-Prog Drill an 8922 MD grass roots well at Ninilchik Feld that will target reserves in T6, T100, T110. T740 sands. Secondary targets include the Objective: Beluga and Tyonek T83, T90, and T142 sands. GEICAL PROGNOSIS .. • FORMA WELL NAME: Kalotsa 4 FIELD: Ninilchik (Pax -Dionne Area) SURFACELOCATION x=209881.34 x=206310.74 ARE: (PROPOSED): BHL y= 2233554.05 y= 2234109.45 PAD ID Kalotsa T PROPOSED To: 8922 MD; 7661 TVD EST KB: 144.5 API: _ TBD -- -- - __— L I__ _......._ _ ._I— EST GL -- ' Drill an 8922 MD grass roots well at Ninilchik Feld that will target reserves in T6, T100, T110. T740 sands. Secondary targets include the Objective: Beluga and Tyonek T83, T90, and T142 sands. DATA COLLECT10NREQUIREMENTS: Mud Logging: Surface Deg. To TD, samples collected at20'intenels LVW Data: LWD Triple Combo surface casing to TD Other Log Data: 1e drilled from the Kalotsa pad and will be drilled to the west-northwest Please provide drilling and final surface location when the best location has been identified and staked. NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HILCORP OR THEIR PARTNERS. Page 37 Version 0 April, 2017 ANTICIPA • FORMA TIONe• —17 EXPECTED FLUID . _. MD TVD IFTI SUBSEA DEPTH Est Pressure EMW • Grad I� Beluga 120 4437 3,341 (3197) 1503 8.7 0.45'. Beluga 135 Will 4639 3,516 (3372) 1582 87 0.45 Tyonek TX gas 4750 3,616 (3472) 1627 8.7 0.45 Tyonek T3 gas 4918 3,767 (3623) 1695 87 0,45 Tyonek T6 gas 5211 4,040 (3896) 1818 6.7 0.45 Tyonek 65 gas 7648 6,417 (6273) 2888 87 045 Tyonek 83 gas 8007 6,768 (6624) 3046 87 045 —_ Tyonek 90 gas8158 6,915 (6771) 3112 8.7 0.45 Tyonek 110 ._gasA 8467 7,217 (7073) 3248 8.7 0.45 Tyonek 140.,.>:` 8745 7,489 (7345) 3370 8.7 045 DATA COLLECT10NREQUIREMENTS: Mud Logging: Surface Deg. To TD, samples collected at20'intenels LVW Data: LWD Triple Combo surface casing to TD Other Log Data: 1e drilled from the Kalotsa pad and will be drilled to the west-northwest Please provide drilling and final surface location when the best location has been identified and staked. NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HILCORP OR THEIR PARTNERS. Page 37 Version 0 April, 2017 U Hilcorp Enc C2ix 23.0 Anticipated Drilling Hazards Kalotsa #4 Drilling Procedure Rev 0 9-7/8" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP between 25 — 45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole -cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of —50 - —60 lbs/I0Oft2 to combat this issue. Maintain low flow rates for the initial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 — 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 38 Version 0 April, 2017 B Hilcorp Kalotsa #4 Drilling Procedure Rev 0 6-3/4" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ viscosifrer as necessary. Sweep hole w/ 20 bbls hi -vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: , 1-12S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 39 Version 0 April, 2017 24.0 Saxon Rig 169 Layout 10 HJUJOW111 =r Kalotsa #4 Drilling Procedure Rev 0 Page 40 Version 0 April, 2017 U Hileorp Ena Company 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Kalotsa #4 Drilling Procedure Rev 0 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. PIU 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 April, 2017 H Hileorp 26.0 Choke Manifold Schematic Kalotsa #4 Drilling Procedure Rev 0 Page 42 Version 0 April, 2017 U Hilcorp Enemy Company Kalotsa #4 Drilling Procedure Rev 0 27.0 Casing Design Information Calculation & Casing Design Factors Ninilchik DATE: 04/20/2017 WELL: Kalotsa #4 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: 2681 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 2681 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.45 psi/ft) and the casing evacuated for the internal stress Page 43 Version 0 April, 2017 Casing Section Calculation/Specification 1 2 3 4 Casing OD 7-5/8" 4-1/2" Top (MD) 0 0 Top (ND) 0 0 Bottom (MD) 1,500 8,922 Bottom (TVD) 1,395 7,661 Length 1,500 8,922 Weight (ppf) 29.7 12.6 Grade L-80 L-80 Connection BTC DWC/C HT Weight w/o Bouyancy Factor (lbs) 44,550 112,417 Tension at Top of Section (lbs) 44,550 112,417 Min strength Tension (1000 lbs) 683 288 Worst Case Safety Factor (Tension) 15.33 2.56 Collapse Pressure at bottom (Psi) 607 3,333 Collapse Resistance w/o tension (Psi) 4,790 7,480 Worst Case Safety Factor (Collapse) 7.89 2.24 . MASP (psi) 457 2,681 Minimum Yield (psi) 6,890 Worst case safety factor (Burst) 15.08- 3.14 Page 43 Version 0 April, 2017 Kalotsa #4 Drilling Procedure Rev 0 Hilcorp Energy C22 28,0 H Hryilco-rp 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-3/4" Hole Section Kalotsa #4 Ninilchik MD TVD Planned Top: 0 0 Planned TD: 8922 7661 Antidoated Formations and Pressures! Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Be] uga120 3341 1503.45 Gas 8.7 0.450 Beluga 135 3516 1582.2 Gas 8.7 0.450 TyonekTX 3616 1627.2 Gas 8.7 0.450 Tyonek T3 3767 1695.15 Gas 8.7 0.450 Tyonek T6 4040 1818 Gas 8.7 0.450 Tyonek65 6417 2887.65 Gas 8.7 0.450 Tyonek83 6768 3045.6 Gas 8.7 0.450 Tyonek90 6915 3111.75 Gas 8.7 0.450 Tyonek 110 7217 3247.65 Gas 8.7 0.450 Tyonek 140 7489 3370.05 Gas 8.7 0.450 TD 7661 3450.0 Gas 8.7 0.450 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date Susan Dionne 5-L-9.-5-- 9-8ppg 1,299' 7,98T 2006 Susan Dionne 6 9.2-9.6ppg 1,578' 4.520' 2008 Susan Dionne 7 9.2-10.1 ppg 1,450' 7.882' 2011 Assumptions: 1. Fracture gradient at shoe (1500' TVD) is estimated at 17 ppg based on field test data. 2. Maximum planned mud density for the 6-3/4" hole section is 10.0 ppg. 3. Calculations assume "Unknown" reservoir contains 100% gas (worst case). 4. Calculations assume worst case event is 100% evacuation of wellbore to gas. Fracture Pressure at 7-5/8" shoe considering a full column of gas from shoe to surface: TVD Frac Grad 1395 ft X 0.884 psi/ft 1233 psi 1233(psi)-[0.1(psi/ft)'1395(ft)]= 1094 psi �C MASP from pore pressure during production mode (Complete evacuation to gas) ✓ 7661ft X0.450psi/ft 3447psi Downhole 3447(psi) - [0.1(psi/ft)'7661(ft)]= 2681 psi Surface ' Summary: � � r 1. MASP while drilling 6-3/4" production hole is governed by frac pressure at 7-5/8" shoe with entire wellbore evacuated togas Page 44 Version 0 April, 2017 Kalotsa Drilling Procedure Rev 0 Hilcorp Eo Company 29.0 Spider Plot (NAD 27) (GnvPrnmvntal fiar•t;nncl DIONNE 4 PAXTON 3 BHA PAXTON 8 m DIONNE 6 BML* '- PAXTON 4 M PAXTON7 BM'•1 KM litalolsP J_TPH Vo�o••opd DINE 5 Bli t 0" C061505,/ lY Kalov J_BIIL C7{p._ , KalolsaJ SHL 4W Pad S001S013W NINILCHIK2 7 DIONHE 7 6HL: Legend • Kalotsa 4 -SHL yX Kalotsa 4-TPH T Kalotsa 4-BHL • Other Surface Well Locations • Other Bottom Hole Locations --- Well Paths �f rn Oil and Gas Unit Boundary ADM2657 0 1.000 2000. 11 Ninilchik Unit Feet Kalotsa 4 Alaska State Plane Zaire 4. NAD27 mhrp Ua.k.,. Lll 6faP Date -2232017 A Page 45 Version 0 April, 2017 H Hilcorp r:�e�cr comer 30.0 Surface Plat (NAD 27) GOVT LOT 2 GOVT LOT 3 Kalotsa #4 Drilling Procedure Rev 0 481• FWL ' #30 n$_ KALOTSA /4 O AS -BUILT POSITION LAT: 60. 06' 15.65878'N Y n LON: 151. 35' 23.80581'W z rc N: 2233554.048' ' H m E: 209881.343' ' - .rv��•=•W- ==- Ililiorp Aluwka, 481' FWL NAD 27"' 1 GOVT LOT ASP ZONE 4 NAD 27 t a ELEV. 126.5' (NGVD29) V U 2281' FSL N: 2232605.56 . E:209377.32 I NOTES 11 1.BASIS-GEODETiCOOMA(A APD wm PMMM IFPGCH=)Is AY OPM SO1V110N FRWt COORDMTESSTAT10t6. MCO AAP.TSEACCNS MP•.MID7At115VAA5t CORSARVTOITIM ISH TYE POSrt10N CF•DID TCN MZVWED90M+E PAD lNE GEODETIC P061110N OF DIO]WAS-UW.jr,, HavEAunnmE OFw06a]991NAHDALaNO1TWE oc tsr]a35.tmv. TFE AIASNA STATECOOAgNATFS fAS%ZOAE i ARE Wn3fi]]t.934 E=135ffiV.5T1 TO EI.EY.I]BTP MGJD293 2. BASIS� CONRiDL MS M 48] PlI1T1LLSIK i mnTcn AT RAI cont o OF A4 �..............•.*� f ...... C�A.• A. SCALE //+` •'•.s�}sm ;+• z� MILCORP ALASKA, LLC KALOTSA A4 NINILCNIK ALASKA H AS -BUILT SURFACE LOCATION - .rv��•=•W- ==- Ililiorp Aluwka, I,LC NAD 27"' tau way SEC. 07 TO1S R13W SEWARD MERIDIAN. ALASKA �* a i Page 46 Version 0 April, 2017 0 Hilcorp 31.0 Directional Plan (wp06) Kalotsa #4 Drilling Procedure Rev 0 Page 47 Version 0 April, 2017 Hilcorp Alaska, LLC Ninilchik Unit Kalotsa Plan: Kalotsa 4 Kalotsa 4 Plan: Kalotsa 4 WP06 Standard Proposal Report 19 April, 2017 HALLIBURTON Sperry Drilling Services HALLIBURTON Hilcorp Alaska, LLC REFERENCE INFORMATION Calculation Method: Minimum Curvature Coordinate (N/E) Reference: Well Plan: Kalotsa 4, True North Sperry Grilling Error System: ISCWSA Vertical(TVD)Reference'. Kalotsa4WP05@144.50usft Scan Method: Closest Approach 3D Error Surface: Elliptical Conic Measured Depth Reference: Kalots84 WP05 (Qo 144.50uM Warning Method: Error Rata Calculation Method: Minimum Curvature Project- Ninilchik Unit Site: Kalotsa SECTION DETAILS Well: Plan: Kalotsa4 Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target Wellbore: Kalotsa 4 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 Kalotse4 WPM 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 Design: Kalotsa 4 WP06 3 1733.65 53.35 289.14 1549.15 189.25 -545.38 4.00 289.14 565.34 3517.50 4 5 6 7 8 3107.15 4629.28 5513.55 8470.19 8922.03 53.35 30.00 12.31 12.31 12.31 289.14 258.50 258.49 258.49 258.49 2369.10 3509.50 4330.89 7219.50 7660.94 550.46 -1586.38 0.00 677.79 -2559.10 2.00 614.39 -2870.61 2.00 488.57 -3488.52 0.00 469.34 -3582.95 0.00 0.00 -149.81 -179.99 0.00 0.00 1644.44 2625.46 Kalotsa 4 wp03 T3 2926.09 3522.43 Kalotsa 4 wp03 T710 3613.56 DDI = 5.740 -750 AStartDir4°/100' : 400' MD, 400'TVD 7501 End Dir : 1733.65' MD, 1549.15' TVD 1p00 00 1500 _ -0 Start Dir 2°/100' : 3107.15' MD 00 7 5/8" x 9 7/8" h O yo ti O 0 2250 'S0' 00 00 A000 Beluga 120 Kalotsa 4 wp03 T3 ... 150o - Beluga 135 - - _ _ - _ - _ _ - _ - _ _ _ - _ __ _ - _ _ _ _ _ Tyonek TX __ .. .. _ _.... _. .._ _... _ Tyonek T3_ _ _ _ - _ - _ _ _ _ _ _ _ _ _ _ Tyonek T6 WELL DETAILS: Plan: Kalotsa 4 CASING DETAILS Ground Level: 126.50 TVD TVDSS MD Size 0.00 2233554.05 209881.34 M° 6'15.659 N 1395.02 1250.52 1500.00 7 5/8" x 9 7/e" +N/ -S 1,00 7660.94 7516.44 8922.03 4 1/2" x 6 3/4" Tool 18.00 1500.00 AStartDir4°/100' : 400' MD, 400'TVD 7501 End Dir : 1733.65' MD, 1549.15' TVD 1p00 00 1500 _ -0 Start Dir 2°/100' : 3107.15' MD 00 7 5/8" x 9 7/8" h O yo ti O 0 2250 'S0' 00 00 A000 Beluga 120 Kalotsa 4 wp03 T3 ... 150o - Beluga 135 - - _ _ - _ - _ _ - _ - _ _ _ - _ __ _ - _ _ _ _ _ Tyonek TX __ .. .. _ _.... _. .._ _... _ Tyonek T3_ _ _ _ - _ - _ _ _ _ _ _ _ _ _ _ Tyonek T6 WELL DETAILS: Plan: Kalotsa 4 Ground Level: 126.50 +E/ -W Northing Easting Latidude Longitude 0.00 2233554.05 209881.34 M° 6'15.659 N 151° 35 23.806 SURVEY PROGRAM Date: 201"M9T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 1500.00 Kalotse4 WPM MWD+SC+sag 1500.00 8922.03 Kalotsa 4 WPM MWD+SC+sag FORMATION TOP DETAILS TVDPath TVDssPam MOPath Formation 3340.50 3196.00 4431.66 Beluga 120 3517.50 3373.00 4638.51 Beluga 135 W1550 3471.00 4750.24 Tyonek T% 3766.50 3622.00 4918.13 Tyonek T3 4039.50 3895.00 5211.26 Tyonek T6 6416.50 6272.00 764828 Tyonek 65 6767.50 61123.00 BDDT5 Tyonek 83 6914.50 6770.00 8158.01 Tyonek 90 7216M 7072.00 8467.12 Tyonek 110 . 2369_1,TVD 7488.50 734400 8745.52 Tyonek 140 6000 6500 7000 End Dir : 5513.55' MD, 4330.89' TVD _Tyonek 65 7500 -_ Tyonek 83 6750 _ - _ _ _ - _ _ _ _ _ _ - _ _ _ - _ boo Tyonek 90 Kalotsa 4 wp03 T110 Tyonek 11 7500 0 . - - _ _ - _ _ - - _ _ _ _ - _ _ _ _ _ - _ Tyonek 140 4 1/2" x 6 3/4 8250 Total Depth: 8922.03'MD, 7660.94'TVD Kalotsa 4 WPO6 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 Vertical Section at 277.46° (1500 usft/in) HALLIBUPTOM® PToiect' Ninilchik Unit coMP,wv CETAIw. Nnrom aaea. L. wt].1,DEu9s'. Twrxalom4 Site. Kalotsa c.lwauon meuoe'MlNmum arrewre Gomq Lcel.. Iy650 Well: Plan: Kalotsa 4 Eno, SSslem ISC. .IAs +w -w ddd We hOre: Ka otsa4 sdon MMnoe: cm:eni l'I..M aO oW OW :x33i'SI Os pM881.H W.6 15.651n I51•)$'SMJ &Yw Plan: Kalotsa 4 WPtl6 YaamiN Me nnod. umr Reno ma 925 REFERENCE INFORMATION lmN am,ma ... r,u. x.m w.e vM.:xw�.Q .�.n 1«sw,fi —'ed MavaurM 0.Np�aN�m: Wblb iCv�w,uM IM]Aua v&IRVEY Ifl00 PROGRAMm WM1: 2016A QT000000 VelpBbtl: Yes WBkn. N,dI From NO To SwroY/Plan Toal 1575 150000 09Y03 haloes OV I MNN•SC•ug 1350 CASING DETAILS TVD NDSS MD Size Noma 139502 1250.52 150000 7-Sl8 ]ST s 979' 1125 7M094 751844 092203 4In 414Vre Mn 900 Edd. 55l13ytdn`3IOWm Sw Qr"l. 3K.I ITM1m,2369.I Rt p 675 Todd Dendo tl9M O$fD, ]550WIy0 i +' 8 Aniip4•,yN Tllu Iq`y ^i FN Dv 173365 MD.1599.IT'IVD G 450 5 3 N 225 S Swt U,J91W:iar A9).MpND $ \ p 0 ]SR'a9]B' 325 450 6]5 iW X050 -3925 -3600 -3375 -3150 -2925 -270'J -2475 -22W 77 -2025 -1803 -1575 -1350 -1125 -9. d75 450 -225 0 .225 west(-W,,66t(+) (430 MStVn) HALLIBURTON Halliburton Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: Kalotsa 4 Company: Hilcorp Alaska, LLC Wellbore TVD Reference: Kalotsa 4 WP05 @ 144.50usft ' Project: Ninilchik Unit Sample MD Reference: Kalotsa 4 WPOS @ 144.51 Site: Kalotsa 8/9/2016 North Reference: True Well: Plan: Kalotsa 4 Dogleg Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 4 Rate Version: Rate Tool Face Design: Kalotsa 4 WP06 VertleaI Section: (°) Depth From (TVD) 0.00 0.00 0.00 (usft) 0.00 Project Ninilchik Unit 0.00 18.00 0.00 189.25 Map System: US State Plane 1927 (Exact solution) • System Datum: Mean Sea Level Plan Sections Geo Datum: NAD 1927 (NADCON CONUS) 0.00 0.00 Using Well Reference Point 0.00 Map Zone: Alaska Zone 04 TVD Depth Using geodetic scale factor Azimuth Depth System (usft) (°) (°) (usft) FSite Kalotsa 0.00 0.00 18.00 -126.50 Site Position: 0.00 Northing: 2,233,473.90usft Latitude: 255.50 60° 6' 14.861 N From: Map Easting: 209,844.16usft Longitude: 151° 35' 24.501 W Position Uncertainty: -- 0.00 usft Slot Radius: 13-3/16" Grid Convergence: 2,224.60 Well Plan: Kalotsa 4 258.50 3,509.50 3,365.00 5,513.55 Well Position +N/S 0.00 Usti Northing: 2,233,554.05 usft Latitude: 60" 6' 15.6 258.49 +El-W 0.00 usft Easting: 209,881.34 usft Longitude: 151° 35' 23.861 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 126.50 Declination C) Tie On Depth: Dip Angle 15.92 +E/ -W Wellbore Kalotsa 4 Magnetics Model Name Sample Date BGGM2016 0.00 8/9/2016 277.46 Design Kalotsa 4 WPO6 Dogleg Build Autlit Notes: +NIS +E -W Rate Version: Rate Tool Face Phase: (usft) (°1100usft) VertleaI Section: (°) Depth From (TVD) 0.00 0.00 0.00 (usft) 0.00 0.00 0.00 0.00 18.00 0.00 189.25 -545.38 4.00 4.00 0.00 Plan Sections 550.48 -1,586.38 0.00 0.00 Measured 0.00 677.79 Vertical TVD Depth Inclination Azimuth Depth System (usft) (°) (°) (usft) usft 18.00 0.00 0.00 18.00 -126.50 400.00 0.00 0.00 400.00 255.50 1,733.65 53.35 289.14 1,549.15 1,404.65 3,107.15 53.35 289.14 2,369.10 2,224.60 4,629.28 30.00 258.50 3,509.50 3,365.00 5,513.55 12.31 258.49 4,330.89 4,186.39 8,470.19 12.31 258.49 7,219.50 7,075.00 8,922.03 12.31 258.49 7,660.94 7,516.44 Declination C) Tie On Depth: Dip Angle 15.92 +E/ -W 73.12 Field Strength (PT) 55,211 PLAN Tie On Depth: 18.00 +NIS +E/ -W Direction (usft) (usft) M 0.00 0.00 277.46 Dogleg Build Turn +NIS +E -W Rate Rate Rate Tool Face (usft) (usft) (°1100usft) (°1100usft) (°I100usft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 189.25 -545.38 4.00 4.00 0.00 289.14 550.48 -1,586.38 0.00 0.00 0.00 0.00 677.79 -2,559.10 2.00 -1.53 -2.01 -149.81 614.39 -2,870.61 2.00 -2.00 0.00 -179.99 488.57 -3,488.52 0.00 0.00 0.00 0.00 469.34 -3,582.95 0.00 0.00 0.00 0.00 41192017 10:19:37AM Page 2 COMPASS 5000.1 Build 81 HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Ninilchik Unit Site: Kalotsa Well: Plan: Kalotsa 4 Wellbore: Kalotsa4 Design: Kalotsa 4 WPO6 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) CI (°) (usft) usft 18.00 0.00 0.00 18.00 100.00 0.00 0.00 100.00 200.00 0.00 0.00 200.00 300.00 0.00 0.00 300.00 400.00 0.00 0.00 400.00 Start Dir 4°/100' : 400' MD, 400 -TVD 0.00 500.00 4.00 289.14 499.92 600.00 8.00 289.14 599.35 700.00 12.00 289.14 697.81 800.00 16.00 289.14 794.82 900.00 20.00 289.14 889.91 1,000.00 24.00 289.14 982.61 1,100.00 28.00 289.14 1,072.47 1,200.00 32.00 289.14 1,159.05 1,300.00 36.00 289.14 1,241.94 1,400.00 40.00 289.14 1,320.73 11500.00 . 44.00 289.14 1,395.02 7 5/e" z 9 7/8" 328.18 1,250.52 1,600.00 48.00 289.14 1,464.48 1,700.00 52.00 289.14 1,528.74 1,733.65 53.35 289.14 1,549.15 End Dir : 1733.65' MD,1541 15' ND 180.48 1,800.00 53.35 289.14 1,588.76 1,900.00 53.35 289.14 1,648.45 2,000.00 53.35 289.14 1,708.15 2,100.00 53.35 289.14 1,767.85 2,200.00 53.35 289.14 1,827.55 2,300.00 53.35 289.14 1,887.25 2,400.00 53.35 289.14 1,946.94 2,500.00 53.35 289.14 2,006.64 2,600.00 53.35 289.14 2,066.34 2,700.00 53.35 289.14 2,126.04 2,800.00 53.35 289.14 2,185.74 2,900.00 53.35 289.14 2,245.43 3,000.00 53.35 289.14 2,305.13 3,100.00 53.35 289.14 2,364.83 3,107.15 53.35 289.14 2,369.10 Stan Dir 2°/100' : 3107.15' MD, 2369.1'rVD 1,862.14 3,200.00 51.75 287.95 2,425.56 3,300.00 50.04 286.61 2,488.64 3,400.00 48.35 285.20 2,553.99 3,500.00 46.67 283.71 2,621.54 3,600.00 45.02 282.15 2,691.20 3,700.00 43.39 280.49 2,762.88 3,800.00 41.78 278.72 2,836.51 -126.50 -44.50 55.50 155.50 255.50 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: Kalotsa 4 Kalotsa 4 WP05 @ 144.50usfl Kalotsa 4 WP05 @ 144.50usft True Minimum Curvature 355.42 1.14 Map Map 209,878.08 4.00 -N/-S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) -126.50 2,233,565.02 0.00 0.00 2,233,554.05 209,881.34 0.00 0.00 0.00 0.00 2,233,554.05 209,881.34 0.00 0.00 0.00 0.00 2,233,554.05 209,881.34 0.00 0.00 0.00 0.00 2,233,554.05 209,881.34 0.00 0.00 0.00 0.00 2,233,554.05 209,881.34 0.00 0.00 355.42 1.14 -3.30 2,233,555.27 209,878.08 4.00 3.42 454.85 4.57 -13.17 2,233,558.93 209,868.29 4.00 13.65 553.31 10.26 -29.57 2,233,565.02 209,852.03 4.00 30.65 650.32 18.19 -52.42 2,233,573.49 209,829.37 4.00 54.34 745.41 28.32 -81.61 2,233,584.32 209,800.44 4.00 84.60 838.11 40.60 -116.99 2,233,597.45 209,765.36 4.00 121.28 927.97 54.97 -158.40 2,233,612.81 209,724.31 4.00 164.20 1,014.55 71.35 -205.63 2,233,630.33 209,677.49 4.00 213.15 1,097.44 89.68 -258.45 2,233,649.92 209,625.13 4.00 267.90 1,176.23 109.86 -316.60 2,233,671.49 209,567.48 4.00 328.18 1,250.52 131.79 -379.80 2,233,694.94 209,504.83 4.00 393.70 1,319.98 155.37 -447.74 2,233,720.14 209,437.47 4.00 464.13 1,384.24 180.48 -520.10 2,233,746.98 209,365.74 4.00 539.14 1,404.65 189.25 -545.38 2,233,756.36 209,340.68 4.00 565.34 1,444.26 206.70 -595.67 2,233,775.02 209,290.82 0.00 617.47 1,503.95 233.00 -671.46 2,233,803.13 209,215.69 0.00 696.04 1,563.65 259.30 -747.25 2,233,831.25 209,140.55 0.00 774.60 1,623.35 285.60 -823.04 2,233,859.36 209,065.41 0.00 853.17 1,683.05 311.90 -898.84 2,233,887.48 208,990.27 0.00 931.73 1,742.75 338.20 -974.63 2,233,915.60 208,915.14 0.00 1,010.30 1,802.44 364.50 -1,050.42 2,233,943.71 208,840.00 0.00 1,088.87 1,862.14 390.80 -1,126.21 2,233,971.83 208,764.86 0.00 1,167.43 1,921.84 417.10 -1,202.00 2,233,999.94 208,689.73 0.00 1,246.00 1,981.54 443.40 -1,277.80 2,234,028.06 208,614.59 0.00 1,324.56 2,041.24 469.70 -1,353.59 2,234,056.17 208,539.45 0.00 1,403.13 2,100.93 496.00 -1,429.38 2,234,084.29 208,464.31 0.00 1,481.70 2,160.63 522.30 -1,505.17 2,234,112.41 208,389.18 0.00 1,560.26 2,220.33 548.60 -1,580.97 2,234,140.52 208,314.04 0.00 1,638.83 2,224.60 550.48 -1,586.38 2,234,142.53 208,308.67 0.00 1,644.45 2,281.06 573.93 -1,656.26 2,234,167.65 208,239.38 2.00 1,716.77 2,344.14 596.98 -1,730.35 2,234,192.48 208,165.87 2.00 1,793.23 2,409.49 617.73 -1,803.13 2,234,214.98 208,093.60 2.00 1,868.09 2,477.04 636.15 -1,874.52 2,234,235.11 208,022.67 2.00 1,941.27 2,546.70 652.22 -1,944.44 2,234,252.85 207,953.16 2.00 2,012.68 2,618.38 665.91 -2,012.80 2,234,268.19 207,885.16 2.00 2,082.24 2,692.01 677.22 -2,079.51 2,234,281.09 207,818.74 2.00 2,149.85 411912017 10:19:37AM Page 3 COMPASS 5000.1 Build 81 Design: Kalotsa 4 WPO6 Planned Survey Halliburton HALL I B U R TO N -- - --- --- Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: Kalotsa 4 Company: Hilcorp Alaska, LLC TVD Reference: Kalotsa 4 WP05 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 4 WP05 @ 144.50usft Site: Kalotsa North Reference: True Well: Plan: Kalotsa 4 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 4 TVDss +N/ -S Design: Kalotsa 4 WPO6 Planned Survey -- - --- --- Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (_) (usft) usftusft ( ) (usft) (usft) (usft) 2,767.49 3,900.00 40.21 276.85 2,911.99 2,767.49 666.12 -2,144.49 2,234,291.55 207,753.99 2.00 2,215.44 4,000.00 38.66 274.85 2,989.23 2,844.73 692.61 -2,207.67 2,234,299.56 207,690.99 2.00 2,278.92 4,100.00 37.15 272.71 3,066.13 2,923.63 696.67 -2,268.96 2,234,305.10 207,629.81 2.00 2,340.23 4,200.00 35.69 270.42 3,148.60 3,004.10 698.31 -2,328.29 2,234,308.16 207,570.53 2.00 2,399.27 4,300.00 34.27 267.96 3,230.54 3,086.04 697.52 -2,385.60 2,234,308.75 207,513.22 2.00 2,455.99 4,400.00 32.90 265.32 3,313.85 3,169.35 694.30 -2,440.81 2,234,306.87 207,457.96 2.00 2,510.31 4,431.66 32.48 264.45 3,340.50 3,196.00 692.78 -2,457.84 2,234,305.75 207,440.89 2.00 2,527.00 Beluga 120 4,500.00 31.59 262.48 3,398.44 3,253.94 688.66 -2,493.85 2,234,302.50 207,404.80 2.00 2,562.17 4,600.00 30.35 259.44 3,484.18 3,339.68 680.60 -2,544.65 2,234,295.67 207,353.81 2.00 2,611.50 4,629.28 30.00 258.50 3,509.50 3,365.00 677.79 -2,559.10 2,234,293.20 207,339.30 2.00 2,625.46 4,638.51 29.82 258.50 3,517.50 3,373.00 676.87 -2,563.61 2,234,292.39 207,334.77 2.00 2,629.81 Beluga 135 4,700.00 28.59 258.50 3,571.17 3,426.67 670.89 -2,593.00 2,234,287.12 207,305.24 2.00 2,658.18 4,750.24 27.58 258.50 3,615.50 3,471.00 666.17 -2,616.18 2,234,282.96 207,281.96 2.00 2,680.55 Tyonek TX 41800.00 26.59 258.50 3,659.80 3,515.30 661.66 -2,638.38 2,234,278.98 207,259.66 2.00 2,701.97 4,900.00 24.59 258.50 3,749.99 3,605.49 653.05 -2,680.70 2,234,271.39 207,217.14 2.00 2,742.81 4,918.13 24.22 258.50 3,766.50 3,622.00 651.55 -2,688.04 2,234,270.08 207,209.77 2.00 2,749.89 Tyonek T3 5,000.00 22.59 258.50 3,841.63 3,697.13 645.07 -2,719.90 2,234,264.36 207,177.76 2.00 2,780.65 51100.00 20.59 258.50 3,934.61 3,790.11 637.73 -2,755.95 2,234,257.89 207,141.54 2.00 2,815.44 5,200.00 18.59 258.50 4,028.82 3,884.32 631.05 -2,788.80 2,234,252.00 207,108.55 2.00 2,847.14 5,211.26 18.36 258.50 4,039.50 3,895.00 630.34 -2,792.29 2,234,251.37 207,105.03 2.00 2,850.51 Tyonek TS 5,300.00 16.59 258.49 4,124.14 3,979.64 625.02 -2,818.40 2,234,246.69 207,078.80 2.00 2,875.71 5,400.00 14.59 258.49 4,220.46 4,075.96 619.66 -2,844.73 2,234,241.96 207,052.36 2.00 2,901.12 5,500.00 12.59 258.49 4,317.66 4,173.16 614.98 -2,867.75 2,234,237.83 207,029.23 2.00 2,923.33 5,513.55 12.31 258.49 4,330.89 4,186.39 614.39 -2,870.61 2,234,237.32 207,026.36 2.00 2,926.09 End Dir : 5513.55' MD, 4330.89' TVD 5,600.00 12.31 258.49 4,415.35 4,270.85 610.71 .2,888.68 2,234,234.08 207,008.21 0.00 2,943.53 5,700.00 12.31 258.49 4,513.05 4,368.55 606.46 -2,909.57 2,234,230.32 206,987.21 0.00 2,963.70 5,800.00 12.31 258.49 4,610.75 4,466.25 602.20 -2,930.47 2,234,226.57 206,966.22 0.00 2,983.87 5,900.00 12.31 258.49 4,708.45 4,563.95 597.95 -2,951.37 2,234,222.82 206,945.22 0.00 3,004.04 6,000.00 12.31 258.49 4,806.15 4,661.65 593.69 -2,972.27 2,234,219.07 206,924.23 0.00 3,024.21 6,100.00 12.31 258.49 4,903.85 4,759.35 569.44 -2,993.17 2,234,215.32 206,903.23 0.00 3,044.37 6,200.00 12.31 258.49 5,001.55 4,857.05 585.18 -3,014.07 2,234,211.57 206,882.24 0.00 3,064.54 6,300.00 12.31 258.49 5,099.24 4,954.74 580.93 -3,034.97 2,234,207.82 206,861.24 0.00 3,084.71 6,400.00 12.31 258.49 5,196.94 5,052.44 576.67 -3,055.87 2,234,204.06 206,840.24 0.00 3,104.88 6,500.00 12.31 258.49 5,294.64 5,150.14 572.41 -3,076.77 2,234,200.31 206,819.25 0.00 3,125.05 6,600.00 12.31 258.49 5,392.34 5,247.84 568.16 -3,097.67 2,234,196.56 206,798.25 0.00 3,145.22 6,700.00 12.31 258.49 5,490.04 5,345.54 563.90 -3,118.57 2,234,192.81 206,777.26 0.00 3,165.39 6,800.00 12.31 258.49 5,587.74 5,443.24 559.65 -3,139.47 2,234,189.06 206,756.26 0.00 3,185.56 6,900.00 12.31 258.49 5,685.44 5,540.94 555.39 -3,160.36 2,234,185.31 206,735.27 0.00 3,205.73 7,000.00 12.31 258.49 5,783.14 5,638.64 551.14 -3,181.26 2,234,181.55 206,714.27 0.00 3,225.90 411912017 10:19:37AM Page 4 COMPASS 5000.1 Build 81 HALLIBURTON Halliburton Standard Proposal Report Database: Sperry EOM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: Kalotsa 4 Company: Hilcorp Alaska, LLC TVD Reference: Kalotsa 4 WP05 @ 144.50usft Project: Ninilchik Unit MD Reference: Kalotsa 4 WP05 @ 144.50usft Site: Kalotsa North Reference: True Well: Plan: Kalotsa 4 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa4 Design: Kalotsa 4 WPO6 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +EJ -W Northing Easting DLS Vert Section (usft) (I (I (usft) usft (usft) (usft) (usft) (usft) 5,736.34 7,100.00 12.31 258.49 5,880.84 5,736.34 546.88 J,202.16 2,234,177.80 206,693.28 0.00 3,246.07 7,200.00 12.31 258.49 5,978.54 5,834.04 542.63 -3,223.06 2,234,174.05 206,672.28 0.00 3,266.24 7,300.00 12.31 258.49 6,076.24 5,931.74 538.37 .3,243.96 2,234,170.30 206,651.29 0.00 3,286.41 7,400.00 12.31 258.49 6,173.93 6,029.43 534.11 -3,264.86 2,234,166.55 206,630.29 0.00 3,306.58 7,500.00 12.31 258.49 6,271.63 6,127.13 529.86 -3,285.76 2,234,162.80 206,609.30 0.00 3,326.75 7,600.00 12.31 258.49 6,369.33 6,224.83 525.60 -3,306.66 2,234,159.05 206,588.30 0.00 3,346.92 7,648.28 12.31 258.49 6,416.50 6,272.00 523.55 -3,316.75 2,234,157.23 206,578.16 0.00 3,356.65 Tyonek 65 7,700.00 12.31 258.49 6,467.03 6,322.53 521.35 -3,327.56 2,234,155.29 206,567.30 0.00 3,367.09 7,800.00 12.31 258.49 6,564.73 6,420.23 517.09 .3,348.46 2,234,151.54 206,546.31 0.00 3,387.25 7,900.00 12.31 258.49 6,662.43 6,517.93 512.84 -3,369.36 2,234,147.79 206,525.31 0.00 3,407.42 8,000.00 12.31 258.49 6,760.13 6,615.63 508.58 -3,390.26 2,234,144.04 206,504.32 0.00 3,427.59 8,007.54 12.31 258.49 6,767.50 6,623.00 508.26 -3,391.83 2,234,143.76 206,502.73 0.00 3,429.12 Tyonek 83 8,100.00 12.31 258.49 6,857.83 6,713.33 504.33 -3,411.15 2,234,140.29 206,483.32 0.00 3,447.76 8,158.01 12.31 258.49 6,914.50 6,770.00 501.86 -3,423.28 2,234,138.11 206,471.14 0.00 3,459.46 Tyonek 90 8,200.00 12.31 258.49 6,955.53 6,811.03 500.07 -3,432.05 2,234,136.54 206,462.33 0.00 3,467.93 8,300.00 12.31 258.49 7,053.23 6,908.73 495.81 -3,452.95 2,234,132.78 206,441.33 0.00 3,488.10 8,400.00 12.31 258.49 7,150.93 7,006.43 491.56 -3,473.85 2,234,129.03 206,420.34 0.00 3,508.27 8,467.12 12.31 258.49 7,216.50 7,072.00 488.70 -3,487.88 2,234,126.52 206,406.24 0.00 3,521.81 Tyonek 110 8,470.19 12.31 258.49 7,219.50 7,075.00 488.57 -3,488.52 2,234,126.40 206,405.60 0.00 3,522.43 8,500.00 12.31 258.49 7,248.62 7,104.12 487.30 .3,494.75 2,234,125.28 206,399.34 0.00 3,528.44 8,600.00 12.31 258.49 7,346.32 7,201.82 483.05 -3,515.65 2,234,121.53 206,378.35 0.00 3,548.61 8,700.00 12.31 258.49 7,444.02 7,299.52 478.79 -3,536.55 2,234,117.78 206,357.35 0.00 3,568.78 8,745.52 12.31 258.49 7,488.50 7,344.00 476.85 -3,546.06 2,234,116.07 206,347.79 0.00 3,577.96 Tyonek 140 8,800.00 12.31 258.49 7,541.72 7,397.22 474.54 -3,557.45 2,234,114.03 206,336.35 0.00 3,588.95 8,900.00 12.31 258.49 7,639.42 7,494.92 470.28 -3,578.35 2,234,110.28 206,315.36 0.00 3,609.12 8,922.03 12.31 258.49 7,660.94. 7,516.44 • 469.34 -3,582.95 2,234,109.45. 206,310.74. 0.00 3,613.56 Total Depth: 8922.03'MD, 7660.94'TVD Targets - Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI.S +E/ -W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Kalotsa 4 wp03 T110 0.00 0.00 7,219.50 488.57 -3,488.52 2,234,126.40 206,405.60 - plan hits target center - Circle (radius 100.00) Kalotsa 4 wp03 T3 - plan hits target center 0.00 0.00 3,509.50 677.79 -2,559.10 2,234,293.20 207,339.30 - Circle (radius 100.00) 41192017 10:19:37AM Page 5 COMPASS 5000.1 Build 81 HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Local Co-ordinate Reference: Company: Hilcorp Alaska, LLC TVD Reference: Project: Ninilchik Unit MD Reference: Site: Kalotsa North Reference: Well: Plan: Kalotsa 4 Survey Calculation Method: Wellbore: Kalotsa 4 3,766.50 Design: Kalotsa 4 WP06 4,431.66 3,340.50 1,500.00 1,395.02 75/8"x97/8" 6,914.50 8,007.54 8,922.03 7,660.94 4 1/2" x 6 3/4" 4,750.24 Formations Vertical Measured Vertical Vertical Depth Depth Depth SS (usft) (usft) 7,648.28 6,416.50 5,211.26 4,039.50 8,467.12 7,216.50 8,745.52 7,488.50 4,918.13 3,766.50 4,638.51 3,517.50 4,431.66 3,340.50 8,158.01 6,914.50 8,007.54 6,767.50 4,750.24 3,615.50 Plan Annotations Tyonek 65 Tyonek T6 Tyonek 110 Tyonek 140 Tyonek T3 Beluga 135 Beluga 120 Tyonek 90 Tyonek 83 Tyonek TX Halliburton Standard Proposal Report Well Plan: Kalotsa 4 Kalotsa 4 WP05 @ 144.50usft Kalotsa 4 WP05 @ 144.50ush True Minimum Curvature 7-5/8 9-7/8 4-1/2 6-3/4 Dip DIP Direction Name Lithology 0 r) Measured Vertical Local Coordinates Depth Depth +N/ -S +E/.W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 Start Dir 4-/100': 400' MD, 400'TVD 1,733.65 1,549.15 189.25 -545.38 End Dir : 1733.65' MD, 1549.15' TVD 3,107.15 2,369.10 550.48 -1,586.38 Start Dir 2°/100': 3107.15' MD, 2369.1 -TVD 5,513.55 4,330.89 614.39 -2,870.61 End Dir :5513.55' MD, 4330.89' TVD 8,922.03 7,660.94 469.34 -3,582.95 Total Depth: 8922.03'MD, 7660.94 -TVD 4/192017 10:19:37AM Page 6 COMPASS 5000.1 Build 81 Hilcorp Alaska, LLC Ninilchik Unit Kalotsa Plan: Kalotsa 4 Kalotsa 4 Kalotsa 4 WP06 Sperry Drilling Services Clearance Summary Anticollision Report 19 April, 2017 closest Approach 3D PtaalmKy Scan on C-mM Survey D.I. (Haft R.MMnce) Refers Design_Kalots.-Plan: Kalotsa E - Kalopa E-Kalotsa6 WM WMI cmo nees: 2.233,551.05 N, 209,881.3E E (60.06' 15.88' N,151.3523.81' W) Gahm HeIgM: 1 IoMa 4 WP05 ($1EE.Mush Scan Range: 0.00 W 8,922.03 usR. M.a.u,W DepN, Swn Ramus Is 1,0WA0usR.Clearance Factor cutoff Is Unllmhep. Ma. Ellipse Sep.r .tl Is UnlimhW C ellc S e Factor Apphi ye .n: 5000.1 Bu1W: 81 Scan Type: GLOBAL FILTER APPLIED: All weilp.th. within 200', 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: Kalotsa 4 - Kalotsa 4 WP06 Cl.at Approach 30 Pmxlmlty acorn on Current Surrey Data (North Refinance) Reference Design: Kalotsa - Plan: Kal.ba 4 -Koalas 4-Kalotes 4 WP06 Scan Range: 0.00 W 8,92203 -aft. Measured Depth, Scan Radius is 1,090.40 waft. Clearance Factor cutoff is unlimited. Max Ellipse Separation is onlim oull She Name Measuretl Minimum StMessured Ellipse @Measurad Clearance Summary Based on Com pans.. Well Name-W.116prs Name -Design Depth Distance Depth Sepanti.n Depth Factor Minimum (-aft) (usft) (usft) (usft) pelt Kalotsa Kaloba 1 - "10tss 1 - Kalotsa 1 947.99 73.10 947.99 87.99 Kablsa l - Kalolaa i-Kab.1 937.65 14,11] Centre Distance Kal.1sa 1- Flaunts1- Kablea1 950.00 73.18 95000 .7 939.59 16.315 Ellipse Separation "lot.. 2-Kelolsa 2-Kaloisa2 2,3)5.90 62).09 2,3)5.00 3)755,366 2268.69 8.320 Clearance Factor Kalotsa 2-Kebba 2-"late.2 602.87 56.25 602.97 51.33 602,64 10.506 Centre Distance tance Kalotsa 2-Kalotsa 2- seldom 2 625.00 54.34 625.00 51.31 624.50 1).81] Ellipse Se P Pant 725.00 58.93 ]25.00 55.36 ]2244 16.532 Clearance Factor on or Plan: K.l.tsa 3-Kalotsa 3-Kablsa 3 WPW 250,00 3038 Plan: Kalolaa 3-Kalataa 3-Kalotsa 3 WP07 250.00 28.79 2 19133 Centre Distance Plan: Kalotsa 3-Kaloba 3-Nablsa3 WPp7 300.00 302 300.00 252 2899.9.80 0] 18433 Ellipse SepareOon 650.00 39.266 650.00 35 64509 11.635 Clearance Factor Paxton Paxton N4-Paudon#4- Pundit #4 2,475.83 31409 2,475.83 Paxlon as - Pamat 44- Paxton #4 24043 4,86541 4,264 Cealm Distance Paxton#4-Passel#4-Pm,nnW 2,525.00 317.71 2,525.03 236.44 4,8)6.50 3969 Eloaece Paudda #8 2,600.00 33848 2,800.00 247.19 4,89397 F.lbn 3)69 Clearance Factor dua#8-PaMar,#8-PaU.n Paxton #8-Paa2on #e - Paxton #9 6,300.00 518.47 6,300.60 49.51 6,400.)4 5.700 Clearance Fachar Paxton#8- Poach #8-Padon 1M 8,375.00 515.24 6,375.00 425.7) 6,46044 5.)59 Ellipse Sepantion fi,do3.i2 514.99 fi.4W.f2 62814 8,484.25 5803 Centre Disbnce Survelr tow Program Fr.m (usft) 10.00 1,50100 To SumeyAna. (..A) 1,500.00 Kaloba 4 WP06 8,922.03 Kalotsa 4 WP06 surrey Tool MWD*SC.sag MWO.SC.sag Hilcorp Alaska, LLC Ninilchik Unit Separation blaming Pass - Pass - Pass - Pass - Pa. - Pass - Pass - Pass- Pass- Pas.- Paas- Pass - Pass- Pass- Pass- a� 19 April 201]- 957 Page 2./5 COMPASS HALLIBURTON Anticollision Report for Plan: Kalotsa 4 - Kalotsa 4 WP06 ---.. _.._..._ _._.........ok„ a...».„.„ey mus us -on romrs. Calculated ellipses inmlpocete audaee errors. Sepemdon is the adust distance bubseen ellGpense. C'unam,e Between centres is the steaight line distance between wellbore centres. clearance Fahr= Oistsnce Between Profiles / (Distance Between snuffles � Ellipse Seperehon). All minion coordinates were calculated using the Minimum Curvature method. Hilcorp Alaska, LLC Ninilchik Unit Pegs 3 o{5 COMPASS NALLIBURTON gPaerY O�Itllnp Project: Ninilchik Unit Site: Kalotsa Well: Plan: Kalotsa 4 Wellbore: Kalotsa 4 Plan: Kalotsa 4 WPO6 Ladder/S.F. Plots REFERENCEIInFZ"'ON ns IWe Rm°nnes; Nam s a. Trve mM V.ys ven: rswl nwl R°mnnn; wwu aw pfu ssnP I ws rrsmR .a mnmc Poslwwa S.WEY pRoG D. 3016 MlTW.00:00 Ya,,, Yes Wrson: DegM1 Fmm Dep111 To SarnpPhn Tool 18.00 1500:00 Na W 4 Wpp9 M1{yeDaSC c 15M00 -K-03 Ya'o .4 K6 pry r W DE S. f :Heb6f4 NAD 1927 (NAD MMMIS) gWto Lmopf YSaF/.W NV' � � gSI: IS50 U. �n � w OW3333550.03 $0881.H W6'15 r59N I51°35'33. WSWN GLOBAL FILTER APPLIED: AI,.I* lM w W 200'.100/1000 ofreWYnm 18.00 Ta 8922.03 CASING DEIAWS w wss m I2�S.Oz ;`so.sz I�C0.00 7-5A 'I 59Ns9 B' WA LL 3.09 m rn Collision Risk Procedures Req. I I I 1.50 - Collision Avoidance Req, No -Go Zone - Stop Drilling) 000 I 0 550 1100 1650 2200 2750 3300 RRSc Measured Depth I ootz9.90 S WOO GKa1015a I' — n p Kd101sa $ y 60.00 `u U _ � 30.00 Kal0bal3 NPo] e U 9.09 0 550 1100 1650 2200 2750 3300 38W 4400 4950 5500 fi050 6600 ]i50 7700 8250 8800 8350 8900 Measured Depth (1100 ustt/in) 6.00 I I WA LL 3.09 m rn Collision Risk Procedures Req. I I I 1.50 - Collision Avoidance Req, No -Go Zone - Stop Drilling) 000 I 0 550 1100 1650 2200 2750 3300 RRSc Measured Depth Davies, Stephen F (DOA) From: David Duffy <dduffy@hilcorp.com> Sent: Tuesday, April 25, 2017 4:55 PM To: Davies, Stephen F (DOA) Cc: Monty Myers Subject: FW: Kalotsa 4 (PTD # 217-063) - Question Hi Steve, Monty asked me to help answer your question, below. You are correct. CIRI owns the triangle. ADL3910105 has three separate portions, none of which fall within the wellpath. GIS is goofy about multi-segment labels, and what we see on the permit to drill is a result. Thanks for bringing it to our attention. We can update the maps if needed. I believe you already have copies of the Ninilchik Unit exhibits. For cross reference, see Tracts 9, 185 and 186 (All portions of ADL 3910105). Regards, David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffv@hilcorp.com This email may contain confidential and / or privileged information and is intended for the recipient(s) only. In the event you receive this message in error, please notify me and delete the message. From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.gov) Sent: Monday, April 24, 2017 10:11 AM To: Monty Myers <mmyers@hilcorp.com> Subject: Kalotsa 4 (PTD # 217-063) - Question Monty, I have a quick question about the lease map on page 45 of this Permit to Drill application. The lease number ADL390105 appears within a small, triangularly shaped property located near the center of the map within Section 12. But a check of DNR Land Administration Website indicates that lease ADL 390105 is located only in Sections 13 and 15 (see screen capture, below). So, it appears as though the small, triangularly shaped property that contains the label "ADL390105"-- and will be crossed by a shallow portion of Kalotsa 4 --is actually part of CIRI lease C061505. Correct? Thanks, Steve Davies AOGCC r File: ADL 390105 Case Detail Case Summary Land Abstract Customer: 000053766 HILCORP ALASKA, LLC 3800 CENTERPOINT DR., STE.1400 ANCHORAGE AK 99503 Case Type: OIL & GAS LEASE COMP File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Total Acres: 174.012 0 Map - Pending Gl. DNR Unit: 780 OIL AND GA'r Status Date: 11,1312002 Date Initiated: 0510112002 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 10/03f2013 Case Subtype: COOK INLET Last Transaction: DR DOCUMENT RECORDED Land Records Meridian: S Township: 0015 Range: 014W Section: 13 Section Acres: 14 Ja: Mericlian: S Township: 001S Range: 014W Section: 15 Sectlon Acres: 160 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska eov. 2 TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development _Service —Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 16� Ile Z JZ POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. API No. 50- _ Production should continue to be reported as function in API number are a of the original 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. (QqMpany 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 sam les are first cau t and 10' sam le intervals thrmigh tar et 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 ro m. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool NINILCHIK, BELUGA-TYONEK GAS -562503 Well Name: KALOTSA 4 __ Program DEV Well bore seg ❑ PTD#:2170630 Company HILCORP ALASKA LLO Initial Class/Type DEV/PEND GeoArea 820 Unit 51432 On/Off Shore On Annular Disoosal n Engineering Appr Date GLS 4/27/2017 fV 18 19 20 21 22 23 24 25 26 27 28 29 2 ......................... Lease number appropriate ......... . . . . . . . . ........... _ _ _ _. Yes _ _ Surface location in CIRI lease C061505; top prod interval & TO in ADL 384372.... 37 3 Unique well name and number _ _ _ .. . . . . . . . . . .... . ......... Yes 39 Yes _ _ _ 4 Well located in_a defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ Yes NINILCHIK, BELUGA-TYONEK GAS — 562503, governed by CO, 701A CMT vol adequate to circulate on conductor. & surfrtcsg . . . . . . .. ............... 5 Well located proper distance from drilling unit boundary.. _ _ _ Yes CO 701A, Rule 3:. There shall be no gas well spacing restrictions. within the. Affected Area, except: _ 4.5'.production casing will be. cemented back to.surface shoe. (cement. packer) 6 Well located proper distance from other wells _ _ _ _ _ _ _ _ _ Yes A). No gas well shall be drilled or completed less than 1,500 feet from the. exterior boundary of Yes 17 Sufficient acreage available in. drilling unit.. . ......... . . . . . . . . . _ _ Yes the Affected Area unless the owner and landowner is the same on both sides oflhe_line., If EL re -drill, has a 10-403 for abandonment been approved ...... _ _ _ _ _ _ .. 8 lf,deviated, is wellbore plat included .. _ _ ......... _ _ _ Yes B) No gas well shall be drilled or completed less than 1,500. feet from an uncommitted tract. 9 Operator only affected parry..... _ _ ... Yes _ _ _ within the Ninilchik Unit unless the well and the uncommitted tract both lie within the same Yes 10 Operator has appropriate bond in force _ ..... _ _ _ _ Yes Participating. Area. Well will lie entirely within the Susan Dionne /.Paxton Participating Area. ROPE press rating appropriate; test to.(put psig in comments)_ _ _ 11 Permit can be issued without conservation order _ _ _ _ _ _ _ Yes As planned, this well conforms to CO 701A, Rule 3 (Well Spacing). Appr Date 12 Permit can be issued without administrative. approval _ _ _ .. Yes Is; presence of H2S gas probable _ . .... SFD 4/26/2017 13 Can permit be approved before 15 -day wait _ _ _ _ _ _ _ _ _ _ _ _ Yes 14 Well located within area and. strata authorized by Injection Order # (put. 104 in. comments) (For NA Engineering Appr Date GLS 4/27/2017 fV 18 19 20 21 22 23 24 25 26 27 28 29 All wells _within .1/4. mile. area, of review identified (For service.well only) _ _ _ _ ... 35 Geology 36 Appr Date 37 SFD 4/24/2017 38 39 All wells _within .1/4. mile. area, of review identified (For service.well only) _ _ _ _ ... NA Public Pre -produced injector duration of pre production less than 3 months (For service well only) _ _ NA _________ Commissioner: Date Noncopyen, gas conforms to A531,05,030Q.1.A),lj.2.A-D) ......... . . . . . . . . . . .. NA_ Conductor string_ provided .... _ _ _ _ _ _ _ _ .......... Yes _ _ _ .... 16" conductor set at 120 ft_ _ _ ____ Surface casing. protects all. known USDWs . ............. . . . . . . . ......... Yes .. Surface casing will be set at 1500 ft, (below all freshwater sources) CMT vol adequate to circulate on conductor. & surfrtcsg . . . . . . .. ............... Yes _ ........ CMT vol adequate to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ Yes _ 4.5'.production casing will be. cemented back to.surface shoe. (cement. packer) CMT will cover. all known productive horizons. . . _ _ Yes Casing designs adequate for C, T, B &, permafrost_ _ _ _ _ _ _ Yes _ _ BTC calculations provided__ Adequate tankage or reserve pit .. _ _ _ _ _ _ _ _ ... _ _ _ _ Yes Rig has steel pits,., all waste to approved disposal well.. Kenai G & I If EL re -drill, has a 10-403 for abandonment been approved ...... _ _ _ _ _ _ .. NA Adequate.wellbore separation_ proposed . . ..... . . . . . . . . . . . ......... . . Yes If diverter required, does it meet regulations _ _ _ _ .. _ _ _ _ _ _ _ _ .. NA Diverter Waived per 20 AAC 25.035(h)(2) ....3 rd well on pad__ .Drilling Fluid program schematic & equip list. adequate.. _ _ _ _ _ Yes Max formation pressure = 3447 psi (8,7 ppg EMW) will drill with .9-10_ppg mud, BOPEs,_do they meet regulation _ _ ... _ _ _ _ _ _ _ _ _ Yes _ SLR 169 has 1 V5000 PSI BOPS_ ROPE press rating appropriate; test to.(put psig in comments)_ _ _ Yes _ _ MASP= 2681 psi. Will test BOPE to 3500 psi ..... . . . ......... . . . . . Choke manifold complies w/API. RP -53 (May 84). _ ... .. _ _ _ _ _ ..... Yes Work will occur without operation shutdown_ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes .. Sundry required for completing and perforating well, Is; presence of H2S gas probable _ . .... No H2S not expected.. Rig has sensors_ and alarms. _ Mechanical condition of wells within AOR verified (For service well only) _ _ . _ .. _ .... NA Permit can be issued.w/o hydrogen sulfide measures _______ _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ Yes . H2S is not. anticipated based on nearby wells. Data presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Expected reservoirpressure is 8,Tppg EMW; will be drilled using 9.0 to, 1A,0.ppg mud._ Seismic, analysis of shallow gas _zones. . . _ _ _ _ .. _ _ NA Additional materials will be onslie to build mud to.1 ppg more than the greatest anticipated mud weight.._ . Seabed condition survey (if off -shore) .. . . . . . . . . . . . . ......... _ _ _ _ NA. _ _ _ ........ ....... Contact name/phone for weekly. progress reports [exploratory only] Geologic Engineering Public Commissioner: Date: Commissioner: Date Commiss' ner Date