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DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-733-20072-62-00Well Name/No. GRANITE PT ST 31-23L2Completion Status1-OILCompletion Date7/23/2021Permit to Drill2210200Operator Hilcorp Alaska, LLCMD10469TVD9249Current Status1-OIL10/1/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD / GR / RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF8/18/20219796 10469 Electronic Data Set, Filename: GP 31-23L2 GAMMA RES.las35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 2MD Final Log.cgm35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 2TVDSS Final Log.cgm35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 5MD Final Log.cgm35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 5TVDSS Final Log.cgm35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 CoMan Final Log.cgm35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 GAMMA RES.ASC35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 2MD Final Log.PDF35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 2TVDSS Final Log.PDF35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 5MD Final Log.PDF35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 5TVDSS Final Log.PDF35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 CoMan Final Log.PDF35513EDDigital DataDF8/18/2021 Electronic File: GP_31-23L2 Definitive Surveys.pdf35513EDDigital DataDF8/18/2021 Electronic File: GP_31-23L2 Definitive Surveys.xlsx35513EDDigital DataDF8/18/2021 Electronic File: ~$GP_31-23L2 Definitive Surveys.xlsx35513EDDigital DataFriday, October 1, 2021AOGCCPage 1 of 2GP 31-23L2GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-733-20072-62-00Well Name/No. GRANITE PT ST 31-23L2Completion Status1-OILCompletion Date7/23/2021Permit to Drill2210200Operator Hilcorp Alaska, LLCMD10469TVD9249Current Status1-OIL10/1/2021UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:7/23/2021Release Date:DF8/18/2021 Electronic File: GP 31-23L2 2MD Final Log.tif35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 2TVDSS Final Log.tif35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 5MD Final Log.tif35513EDDigital DataDF8/18/2021 Electronic File: GP 31-23L2 5TVDSS Final Log.tif35513EDDigital Data0 0 2210200 GRANITE PT ST 31-23L2 LOG HEADERS35513LogLog Header ScansFriday, October 1, 2021AOGCCPage 2 of 2M. Guhl10/1/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 18" B 603' 13-3/8" J-55 3,665' 9-5/8"N-80/S-95 7,287' 7" N-80 9,149' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 7/13/2021 7/7/2021 ADL 018761 19-001 N/A 10,283 / 9,149'75 319' / 319' 10,469' / 9,249' MWD / GR / RES Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 10,283' - 10,469' 9,149' - 9,249' Fish (BHA) Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing 70.59# 61# 604' Surface 8,062' Gas-Oil Ratio:Choke Size: 10,361' Per 20 AAC 25.283 (i)(2) attach electronic information 40# / 43.5# 10,283' Surface 7,117' DEPTH SET (MD) 9,799' / 8,742' PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 29# 260306 260295 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 2541381 BOTTOM TOP 12-1/4" Surface 16" HOLE SIZE AMOUNT PULLED 50-733-20072-62-00 GP 31-23 L2 263287 2544567 326' FNL, 1665' FEL, Sec. 23, T10N, R12W, SM, AK CEMENTING RECORD 2541387 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7/23/2021 2365' FNL, 1253' FWL, Sec. 13, T10N, R12W, SM, AK 332' FNL, 1675' FEL, Sec. 23, T10N, R12W, SM, AK 221-020 Granite Point Field / Middle Kenai Oil Pool 105.0' 10,469' / 9,249' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 22" Surface 3,933' 2435 sx Class 'G' 670 sx Class 'G' 800 sx Class 'G' 7,867' 10,199'4-1/2" 12.6# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 1182 sx Class 'G'8-1/2" TUBING RECORD Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 3:39 pm, Aug 18, 2021 RBDMS HEW 8/19/2021 Completion Date 7/24/2021 HEW GDSR-8/23/21SFD 8/23/2021BJM 9/30/21 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 10266' 9134' 10266' 9134' 10283' 9149' Tyonek C5 10266' 9134' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Kicked off from Parent Well Drilling Reports, Definitive Directional Survey, Wellbore Schematic Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME (GP 31-23) Tyonek C5 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 8.18.2021Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.08.18 15:10:36 -08'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 8/11/21 SCHEMATIC Granite Point Platform Well No: GP 31-23 / L1 / L2 Completed: 04/29/21 GP 31-23L2 TD = 10,469’ MD / 9,249’ TVD PBTD = 10,469’ MD / 9,249’ TVD GP 31-23L1 TD = 11,096’ MD / 9,804’ TVD PBTD = 11,096’ MD / 9,804’ TVD ADL: 18761 PTD: 167-084 / 221-018 / 221-020 API: 50-733-20072-00 / -60-00 / -62-00 CASING DETAIL Size Wt Grade Conn ID Top Bottom 18" 70.59 B Surf. 604’ 13-3/8" 61 J-55 DV Tool 12.515” Surf. 2,230’ 13-3/8” 61 J-55 Buttress 12.515” 2,230’ 3,933’ 9-5/8" 40 N-80 Buttress 8.835” Surf. 295’ 40 N-80 LTC 8.835” 295’ 3,801’ 43.5 N-80 LTC 8.755 3,801’ 5,173’ 43.5 S-95 STC 8.755 5,173’ 8,062’ 7" 29 P-110 X-line 6.184” 7,867’ 11,196’ TUBING DETAIL 4-1/2" 12.6 L-80 IBT 3.833 Surf. 9,783’ 4-1/2" 12.6 L-80 IBT 3.833 9,799’ 10,199’ Jewelry Detail #Depth (MD) Depth (TVD)ID OD Item 1 319’ 319’ 3.813 5.960 TRSV, NE-SLIM (Halliburton) 2 2,604’ 2,509’ 3.958” 7.000” GLV #1 – IPO-15 4,784’ 4,416’ 3.958” 7.000” GLV #2 – IPO-15 6,364’ 5,800’ 3.958” 7.000” GLV #3 – IPO-15 7,384’ 6,687’ 3.958” 7.000” GLV #4 – IPO-15 8,203’ 7,408’ 3.958” 6.000” GLV #5 – IPOC-1 8,926’ 8,006’ 3.958” 6.000” GLV #6 – IPO-1 9,644’ 8,612’ 3.958” 6.000” GLV - Orifice 3 9,783’ 8,729’ 4.000” 6.000” 15' 5.000 PBR w/ 4 1/2 LTC Pin 9,799’ 8,742’ 4.000” 5.870” 7 x 4 1/2" 23-32# Hydraulic Isolation Packer 4 9,873’ 8,805’ 3.810” 5.820” X Nipple 5 9,886’ 8,816’ 3.810” 5.500” Sliding Sleeve (Open Up) 6 10,199’ 9,078’ 3.960” 5.170” WLEG 7 10,361’ 9,204’ FISH (BHA) 8 11,028’ 9,759’ FISH (BHA) Perforations Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail 9,860’ 9,861’ 8,794’ 8,795’ Squeezed 9,866’ 9,867 ‘ 8,799’ 8,800’ Water Shut Off 9,911’ 9,921’ 8,837’ 8,846’ Open 9,941’ 9,971’ 8,863’ 8,888’ Open 10,100’ 10,101’ 8,996’ 8,997’ Squeezed 10,254’ 10,260’ 9,124’ 9,129’ Open 10,260’ 10,275’ 9,129’ 9,142’ Open 10,275’ 10,280’ 9,142’ 9,146’ Open 10,280’ 10,445’ 9,146’ 9,281’ Open 10,561’ 10,578’ 9,376’ 9,390’ Open 10,654’ 10,681’ 9,452’ 9,474’ Open 10,730’ 10,731’ 9,515’ 9,515’ Squeezed 10,895’ 10,897’ 9,650’ 9,651’ Open 10,897’ 10,987’ 9,651’ 9,725’ Open 11,014’ 11,016’ 9,747’ 9,749’ Open 11,016’ 11,176’ 9,749’ 9,878’ Open 10,283’ 10,469’ 9,149’ 9,249’ Open Hole (L2) 11,027’ 11,096’ 9,758’ 9,804’ Open Hole (L1) KB: 105’ MWL PBTD = 11,147’ TD = 11,200’ 5 18” 2 3 4 Top of whipstock (L1) 11,021’ Top of whipstock (L2) 10,283’ 9-5/8” 6 7 8 1 13-3/8” 7” CBL 4/25/21 EST TOC 6,740’ Clean out to 11,094’ 04/25/21 TOL 7,867’ Activity Date Ops Summary 7/4/2021 Continue trying to engage fish with Overshot Not able to stay engaged to the fish, POOH holding 260psi WHP to inspect the OS, cut pipe and re-head. OOH, close SSSV with 260psi WHP. Bleed off WHP and prep to pull BHA BHA OOH, Over Shot shows definite signs that it was over the fish but didn't grab it. Cut 250' of coil to move the wear spot. Prep coil for CTC. MU Dimple Connector. Pull test test to 50k. MU BHI Lower Quick Connect, install floats and PT to 4000psi Discuss plan forward with ODE. Decision is made to set whipstock because the remaining GS spear is not compatible with the BHI fish neck. L/D fishing BHA. Prep whipstock. Whipstock is missing a brass shear screw that secures the top whipstock to the setting tool. Make one from brass shear stock. Remove tree cap, set on deck. Rig up BHA #8 and swing over to well deck, have to lay it down to re-rig it twice to get it to pick up right. Make up injector to well. Install fusible cap. Open EDC. Line up valves. Start pumping through CT. Stripper is leaking. Shut down and clean up OBM on and around tree. Pump WHP to 270 psi, open SSSV. RIH, pump min rate through open EDC with pump trips set low. Slow down through SSSV, nothing seen. While RIH follow MPD schedule as a training exercise for Driller. Log GR tie-in from 9840'. 7/5/2021 Continue log tie in pass. Correct depth -3'. PUH to 9800' bit depth then log CCL for TOWS placement. Verify collars and above and below. Set TOWS at 10279' - Pinch Point at 10284' WS setting tool sheared at 3000psi, WOB came up to 1.4k then fell off to 0.4k. RIH to see if WS set, moving down hole WS did not set. Prep to POOH, slow down at the TT in case the WS is still on the setting tool. Pull 2.6k over at the TT, RIH, PU and tagged again at calculated depth if the WS is on. RIH to bottom and stack out on setting tool shear bolts to release. RIH to bottom and spud BHA 5x at max WOB and speed. PUH to TT and see if WS sheared off. Pulled through the TT clean, POOH holding 275psi WHP. OOH, crane loading 2 ISO's on the platform. Pull & LD the BHA. BHA OOH, prep for testing BOP's tonight Prep for BOP test. Close swab, SSV. Purge test pump with OBM and test. Won't pump mud, purge with clean LVT. Remove floats from UQC. Grease choke and tree valves. Remove tree cap. M/U injector to well. Finish greasing. LO/TO on reel then grease IRV. Make rig announcement then shell test to 280 / 4200 psi, good. Install JIC fitting and hose to ground on stripper needle valve. Fill up stack to stripper needle valve with mud pumps. Try test pump for BOP test #1, not pressuring up. Doesn't appear to be pumping. Line up to use mud pump for BOP test. First test is IRV, CT packoff, BOP1, BOP3, Kill Line Gate Valve, and 2 choke valves. Good low, Slow bleedoff on high pressure, isolate valves 1 by 1 determine IRV passing. Move on to test #2 so IRV can be greased. Test #2 is Blind / Shear, Kill HCR, BOP2, and 3 choke valves. Blind / Shear fail, bad chart and fluid from leak path. Continue testing. 7/6/2021 Continue testing BOPE. Test 1 & 2 Failed. Test pump will not build more than 150psi with LVT, block valves shut in at the discharge end of the pump with 0psi increase, pump is primed, PRV is good. Test 3-9 completed with test joint Stab injector on to retest components for tests 1 & 2. Test H2S & LEL Gas alarms. Perform Drawdown test. BOP Test completed. Remove injector, install floats & test. MU Northern Solutions WS BHA. M/U injector to well. Install fusible cap. Finish valve checklist. Line up through MPD choke, put 270 psi on WHP. Open SSSV. RIH, slow to 20 ft/min through SSSV, nothing seen. Set trips low, pump min rate though open EDC while RIH. Slow down passing all jewelry. Tie-in depth, correct -4'. Perform CCL across whipstock setting area. Get up weight 50k. Start 9# mud down CT. RIH to 10980'. POOH lay in 9# mud 1:1 to 10280'. Pump 2 down swap to pump 1 while POOH. RIH to whipstock setting depth then pick up to 45k just below up weight. Park here and review tie-in and CCL logs. Production disruption, loss of power to BHI cab and other parts of drilling deck. Large flare for a short time. Regain power, check all systems. Close EDC. Pressure up CT slowly gaining DWOB. Shears at 4200 psi. DWOB goes to 7k briefly then goes to 0.7k. RIH slowly to confirm set, set 3.4k solid set. Whipstock set @ 10L orientation with pinch point at 10284.5'. POOH, pump 1 bpm through CT while POOH. Tag stripper. Trap 320 psi WHP and close SSSV. Bleed off WHP flow check through BOP3 is good. Wait for flare to reduce size. If wind shifts the flare would be too close to personnel on work platform around well. Flare is down. PJSM then start BHA swap. Remove 4-point chains. Lift off well, fittings on jacking cylinder contacting new scaffold extension. Rework scaffold brackets. 7/7/2021 Platform system appears to be stable, talked to Ops Lead and they only have a couple wells to bring back online and flaring should be minimal/back to normal. PU the injector and LD the WS setting BHA. PU the Milling BHA After getting stabbed on one of the CT hands saw a few Gripper Block springs that are bent. Get Hydra- Rig Mechanic to inspect before RIH. Replace springs Springs replaced, pressure up WHP to 300psi to open SSSV and RIH Log tie in with -3' correction. RIH and tagged pinch point at 10286'. PU and get pumps up to rate Shut down pumps, auger stopped running, if fluid runs over the shakers and the auger is not running it could fill up and run over. Stop to fix auger Start milling window at 10285.7' Continue milling window from 10289.0' to 10293.1'. 2.4 / 2.4 BPM In / Out. Mud weight 7.44 / 7.32 ppg In / Out. ECD is 8.5# with 260 psi WHP. Continue milling window. At 10293.1' DWOB and motor work erratic, likely mill exit at this depth. Continue time milling 1 ft/hr to let string reamer work the bottom of window. Pump #1 runs out of fuel and shuts down. Switch to pump #2 and it starts leaking from packing seal O-ring. Work on priming pump #1. Get pump #1 running. Continue milling rathole from 10294'. 7/8/2021 Yellow Jacket Pump back online, continue milling bottom of window and Rat Hole. Sample from 10297' shows 20% Sand. Milled rathole to 10303' MD. Pooh. Jet tubing tail. Open EDC. Pump 1 overheating. Swap over to pump 2. Packing leaking / overheating. Swap back to pump #1. Pooh. 10160' to 9001' Injector carrier spring clips showing damage during inspection. Hydrarig rep recommended increasing chain tension. Replace spring clips Pooh from 8944' md. Jet across SSSV. puh to 226' md. Stripper started leaking. Driller increased to 3000 psi. Closed Annular and down hole SSSV. Make notifications. Begin clean up. Finish cleanup of OBM on BOP stack. Retract stripper to inspect. Stripper element is gone, energizer is mostly gone. Extrusion rings and brass still ok. Source new energizer component from shore. Stripper energizer arrives. Assemble stripper. Open annular. PT stripper to 130 psi against SSSV. Will do regular 250 / 4000 psi test later when BHA is out of well. Finish trip OOH. PJSM then remove window milling BHA. Mill is 3.80" no-go, reamer is 3.79" no-go. Make up nozzle and get back on well. PT stripper to 250 / 4000 psi, good. Make up build section BHA. 7/9/2021 Stab injector. PT QTS to 3500#. Increase wellhead pressure to 600#. Open SSSV with 4000#. Rih. Rate In: 0.42 bpm, Rate out: 0.78 bpm. MW in: 7.40 ppg, MW out: 7.36 ppg. Following choke step down for constant BHP at window. Log tie in for a -6.5' correction. Bring both pumps on together to establish drilling parameters Problems with MP#1, Rebuild 3 times. Fix leak. End cap needs to be replaced. If not could damage fluid end. Discussions with Yellowjacket management. Source parts for fluid end and sensors to address lockup issues. Line up valves and circ min rate with pump #2. Pick up CT about 20' then stop and close upper pipe / slips so CTU power pack can be shut down for oil change. After oil change roll CT back and inspect pipe, nothing seen. Yellow Jacket mechanic arrives. Install manual lockup switches on both pumps and run cables for them. Build bracket for lockup toggle switches. Extend pump #2 pop-off line away from edge of mud tank to center. Mobilize parts for pump #1 fluid end from shore. Repair pump #1 fluid end. 6/23/2021Spud Date: Well Name: Field: County/State: GPF GP 31-23L1 & L2 Granite Point Field Hilcorp Energy Company Composite Report , AK Looks like first WS did not set. BOP Test completed. Whipstock set @ 10L orientation with pinch point at 10284.5' If wind shifts the flare would be too close to personnel on work platform around well. Stripper element is gone, energizer is mostly gone. cleanup of OBM on BOP stack. Stripper started leaking. MU Northern Solutions WS BHA. Production disruption, loss of power to BHI cab and other parts of drilling deck. Wait for flare to reduce size. r Start milling window at 10285.7' Closed Annular and down hole SSSV. Mud weight 7.44 / 7.32 ppg In / Out. PT Decision is made to set whipstock because the remaining GS spear is not compatible with the BHI fish neck. have a couple wells to bring back online and flaring should be minimal/back to normal. Continue testing BOPE. T stripper to 250 / 4000 psi, good. T s Set TOWS at 10279' Switch from GP 32-23L1 to L2 after BHA stuck just outside the window. 7/10/2021 Continue installation of parts into Pump#1. Run Pump #1 for 30 minutes at drilling rate. Temperature holding solid. No leakage Log tie in with +1.5' correction. Rih to 10250' MD. Rate in: 0.72 bpm, Rate out: 0.72 bpm Circulating pressure: 910 psi. MW in: 7.39 ppg, MW out 7.34 ppg. Rih weight: 16K, PU weight: 54K. Issues getting through window. Tried multiple toolfaces, Min rate, No Rate. Pump #1 issues. Troubleshoot lube oil system. Rebuild fluid end with new o-rings. Assemble. Roll pump and verify lube oil lubricating packing. Pooh for window dressing assembly. Rate in: 1.20 bpm, Rate out: 0.78 bpm. Circulating pressure: 1249 psi. MW in: 7.39 ppg, MW out 7.36 ppg Close SSSV. Trap 550 psi below flapper. Draw pressure down 200 psi. Annular BHP holding solid. Open drilling choke while circulating minimum rate. Tag up. Perform flow check. Well Static. PJSM. Remove fusible cap from SSV. Lay down build BHA. Bit covered in what appear to be fine clay. Make up cleanout / window dressing BHA. Perform injector checks prior to running in hole. Pump up WHP to 550 psi and open SSSV. RIH pump min rate. At 3100' injector chain tension cylinder is seen leaking. POOH. Tag stripper, close SSSV and bleed off. RIH 40' and center pipe with annular, then close upper pipe / slip rams. Prep to remove chain tension ram. Shut off power pack. Bleed off chain tension and traction. Remove chain tension cylinder and inspect, o-ring is damaged. Replace and install cylinder. PT is good. Open rams and roll back, nothing seen on pipe. Pump up WHP to 550 psi and open SSSV. RIH pump min rate. Log tie-in from 9860'. Stack 4k wt at 9884' then push through. Close EDC and pump 1.5 bpm while logging. Up weight at 10150 is 55k. Pass tubing tail and go to 2.7 bpm pump #1. Packing leaking. Swap to pump #2, packing 2 pod overheating. Pump min rate with pump #2 while troubleshooting pumps. 7/11/2021 Troubleshoot lube oil system. Pump one working now. Get pump 2 back together. Test. Log tie in with +1.5' correction. Bring rate up to 2.70 bpm. Rih at 1 fpm from 10282' to 10303' MD Seen 100 psi of motor work start at 10293.5' and going away at 10295.3'. Perform reaming passes at as milled and 15 deg L / R. Perform Dry drift to 10303' MD. No issues. Pooh. MW in: 7.44 ppg , MW out: 7.29 ppg. Rate in: 3.0 bpm, Rate out: 2.70 bpm Circulating pressure: 3548 psi. Maintain pressure schedule while tripping -Jet across SSSV, Trap 575 psi below valve. Close valve. Bleed pressure down to 200#. Watch PWD pressure. Holding solid. Open drilling choke. Circulate min rate to keep hole full. Tag up. Perform flow check. Well is static. Remove Fusible cap from SSV. PJSM. Lay down mill assembly - Make up build BHA. Equalize pressure above SSSV with 600 psi. RIH with build BHA RIH to 4100'. Stripper pressure acting erratically. Stop CT. Inspect hoses at injector and bulkhead in Ops cab, no oil leaks seen. Close upper pipe/slips and annular, inspect stripper element. Element and energizer are bad, replace. Has 34k ft on it. PT stripper to WHP (550 psi) good. Will do regular PT next time OOH. Continue RIH from 4100'. Tie-in depth, correct -8'. Pass tubing tail, run pump #2 for 15 min at drilling rate, solid. Run pump #1 for 5 min at drilling rate, ok. Get up weight 55k. Pass through window at 10L, 0 pump, 15 ft/min with no issues. Start taking wt at 10299' bring pumps on. Drill from 10300' to 10318'. 2.68 / 2.68 bpm @ 3700 psi free spin. 7.45 / 7.33 ppg In / Out. Window ECD 8.53# with 300 psi WHP Continue drilling from 10318'. Have to pick into 7" twice for toolface issues and reboot BHI computers. 7/12/2021 Continue drilling ahead in build. Drilling 4-1/4" Build. Free Spin: 3547 psi @ 2.58 bpm. MW in: 7.46 ppg, MW out 7.31 ppg. Rate in: 2.64 bpm, Rate out: 2.64 bpm Circulating pressure: 3547 psi to 3688 psi. Lost motor work at 10364' MD. PU off bottom with -14K WOB overpull. Drilling 4-1/4" Build to 10430' MD. Free Spin: 3547 psi @ 2.58 bpm. MW in: 7.46 ppg, MW out 7.31 ppg. Rate in: 2.64 bpm, Rate out: 2.64 bpm Circulating pressure: 3547 psi to 3688 psi. Picking off bottom frequently to get drilling again. Land build, Start wiping hole prior to pulling out Pooh for lateral / Clean 7". MW in: 7.47 ppg, MW out 7.33 ppg. Rate in: 2.58 bpm, Rate out: 2.58 bpm Circulating pressure: 3525 psi. Rih weight: 20K, PUW: 52K Window ECD: 8.5 ppg @ 277 psi wellhead. Pull through SSSV without issue. Trap 593# underneath valve. Close SSSV. Bleed Annular BHP down to 256 psi. Held solid after 10 minutes. Open choke. Circulate min rate while pulling to surface. Perform 10 min flow check. Well static. Brake at QTS. Inspect last 50' of coil while pooh. Pull build bha out of well. Lay down motor and bit. Perform weekly BOPE function test. Inspect packoff and energizer element. Good. PT packoff to 250/4000 psi. Good. Packing in MP #1 leaking. Replace leaking packing in MP #1. Function and pressure test at drilling rate. Good test. Replace leaking packing in MP #2. Function and pressure test at drilling rate. Good test MU Lateral BHA w/1.2 degree motor and RWD2ST3053.750T HCC 4.25" bi-center bit. MU injector to well and PT QTS. Equalize and open SSSV. RIH w/lateral BHA. 7/13/2021 Continue with trip in. Log tie in with -6.5' correction. PUW 57K. Close EDC. Run through window without issue. Drill Lateral. Free Spin: 3747 psi @ 2.64 bpm. Rate in: 2.64 bpm, Rate out: 2.58 bpm. MW in: 7.53 ppg, MW out: 7.37 ppg. ROP 30-40 fph, WOB: 1.9- 2.7K. Lost WOB and motor work. Attempt to pick up. No Joy. Orient with HOT without issue. Differentially Stuck. Circulated bottoms up. Shut down pumps. Let relax. Pull to 105K multiple times. Pump 20 bbls of LVT-200 oil. Spot 5 bbls out bit, Relax 15 min. Pull 100K, Still no reaction on BHA. Pull into tension at 77K. Let relax for 30 min. Pump another 5 bbls out for a total of 10 bbls. Stack weight. Pull 100K. No reaction. Pump another 5 bbls out for a total of 15 bbls. Stack weight. Pull 100K. No reaction. Let wellbore relax. Attempted pulling 1 more time. No joy. Break Circulation. -Rate In: 2.46 bpm, Rate out: 2.46 bpm Circulating pressure: 2826 psi. MW in: 7.46 ppg, MW out: 7.46 ppg. Divert 20 bbls of LVT back to mix pit. Mix 20 bbls LVT with 4 drums of MiSwaco DeepKleen Pump 20 bbls of LVT/DeepClean pill. Pump 10 bbls out bit and around bha and work coil in tension/compression. Pump final 10 bbls out around bha and work coil in tension/compression. No Joy - discuss options with SR Drilling Forman and Drilling Engineer Pressure up well while pumping down coil and surge in attempt to pull free. Surge at 100 psi, 500 psi and 1000 psi with no coil movement. Surge well at 1500 psi and coil appeared to pull free briefly. Unable to move injector. Investigate and find injector gripper blocks damaged and missing. Notify SR Drilling Foreman and ToolPusher. Secure well by shutting the uppermost BOP pipe/slip rams. Manually lock rams. Begin injector inspection and repair. Fill well through mud cross periodically and find well stable with fluid column at surface. Continue injector inspection and repair. Remove and inspect all coil tubing injector gripper blocks. 7/14/2021 Continue injector inspection and repair. Remove and inspect all coil tubing injector gripper blocks. Multiple blocks broke. (10) Carrier blocks on one chain, (8) Carrier blocks on other chain Replacing injector chains Complete installing new injector chains. Install gripper blocks and inspect. Move PRT jacking frame back into original position and secure Apply traction pressure to chains and attempt to push/pull against pipe/slip rams. Injector load cell not reading. Troubleshoot and repair. 7/15/2021 Continue to troubleshoot injector load cell problem. Take pictures and send to Hydrarig for plan forward. Test new lube system on both pumps. Worked well to 3.5 bpm on each pump. Begin offloading OBM product. Prepare tools for fishing bha. Repair injector load cell issue per Hydra Rig engineer with relief cuts and damaged flange. Remove failed fan bearing on CTU power pack Bleed injector weight cells and calibrate. Verify with hydraulic pressure versus weight indicator. Receive and install new pulley bearings in CTU power pack. Push/pull test upper set of pipe/slips with 10k. Attempt to PU to 60k and coil moved through slips at 40k. Close lower set of pipe/slips and run manual locks in. Push/pull test 10k. Drain fluid column. Open upper set of pipe/slips. LOTO power pack and open pipe ram bonnets. Remove and inspect upper 2 3/8" pipe/slips. Slips are damaged and points are smeared. Replace with new pipe slips. MU bonnets to body of BOP. Shell test bonnets to 1000 psi. No leaks observed. PU coil to 60k and open pipe/slips. 30k weight hanging on coil. Attempt to POH twice at 95k No Joy. Circulate out 20 bbl MI Deep Clean pill in hole. Circulate 1.5 times bottoms up at max rate. 7/16/2021 Finish circulating DeepKleen pill out. Transfer to ISO. PJSM, Perform disconnect procedure per BHI. EDC in disconnect position. Pull into tension. No luck. Never lost communication with tool. Attempt to reconnect. Appears we reconnected. Open EDC. Circulate 2 bottoms up at max rate of 3.2 bpm. BHI finish disconnect. Still no release. Pressure up wellbore and coil. Working up in 500 psi increments to as high as 1500 psi. Rapidly dump pressure. Still no luck disconnecting. Move fluids around. PJSM, Pump 67 bbls LVT and 40 bbls of diesel. Circulate into Tubing x Coil Annulus. Spotting diesel in open hole. Chase with 7.4 OBM. Let well reach equilibrium Continue to let LVT and Diesel soak around BHA. Rebuild 2 3/8" pipe combi rams. Transfer 133 bbls of 8.5 ppg KWF back to platform beam tanks for storage. Pull 95k without any coil movement. Pull 95k without any movement. Clean and organize center bay. Roll and prepare used 6100 injector chains for shipping. Continue to prepare for N2 pump and tanks. Differentially Stuck. weekly BOPE function test. Rebuild 2 3/8" pipe combi rams. Remove and inspect upper 2 3/8" pipe/slips. Slips are damaged and points are smeared. Attempt to PU to 60k and coil moved through slips at 40k. issues and reboot B 7/17/2021 Continue to allow diesel / LVT soak. Offload mud product, and two ISO to make room for N2 equipment that is coming. Consolidate equipment on deck. Continue to allow diesel/LVT to soak. Clean and organize drill deck and equipment. Attempt to work coil to 95k. Coil still stuck. 7/18/2021 Clean pit for diesel return. Break circulation. Circulate and capture LVT and Diesel. Offload 120 bbl crude ISO. Begin displacement of coil. 3 bbls OBM ran over PFMS cuttings box. Make all required notifications. Clean up deck. Empty cuttings box and swap out vac system tote. Finish pumping 80 bbls dead crude through coil and let soak. Work coil to 95k with no movement. Cycle BHI orienter. Send disconnect signal again from BHI. Pull to 95k with no movement. Pump remaining crude. Total pumped = 118 bbls. Continue to let crude soak. Clean and organize drill deck. 7/19/2021 Cycle Pipe to 95K. No Joy. Circulate remaining crude around and to surface. Let soak. Multiple attempts to free. Circulate out dead crude. Segregate at pump back to production. Clean pits to ISO. Offload OBM to ISO. Work boat. Offload N2 Pump, and Nitrogen. Send ISO of OBM / in for storage. RU N2 pump and tanks. Ensure proper line up through choke and MGS. Displace coil and well with 160 bbls of diesel. Finish RU of N2 pump. PJSM. PT N2 line to 250/4000. Good. Pump 55k SCF N2 taking returns through manual choke and MGS. Work coil after coil displaced with N2. Still stuck. Continue pumping N2 and displace CT x T annulus. N2 @ surface when 133 bbls total returned through return MM. Bleed down tubing pressure to 0 psi and work coil. Still stuck. Leave coil in tension. Clean and organize drill deck. 7/20/2021 Continue let BHP climb back up. Stack in compression. Displace coil and well to FIW. Transfer diesel to operations well containment tank. Empty pits 1,2,3. Continue to circulate hole clean. Circulate hole with FIW. Shut down pumping and verify no flow for 30 minutes. Work boat and offload eline units and coil recovery tools. Transfer fluid from pits to ISO for offloading. Pull coil to 55k and shut upper combi rams. Pull/push test 10k. Good. Close manual locks. Release pressure on coil traction cylinders and strip injector up. Secure coil with slips and dog collar. Hot tap coil and confirm 0 psi in coil. Cut coiled tubing and pull up to expose eline. Secure eline with double clamps and lifting sling. Pull eline with platform crane in multiple picks until 4k weight. Eline should have released at ~ 3k with eline wt and anchor set screw. Stop job and evaluate lifting equipment and plan forward. MU cut end of eline to eline unit drum. Begin increasing tension beyond 4k. Pull to 5.5k and can't pull. 7/21/2021 PJSM. RU cable clamps. On elevators with crane. Pull to 4700#, Anchor freed. Hanging weight 2100#. Appears we have all the cable. Pull out of hole with 5/16"e- line. E-line Anchor recovered. All e-line out of coil. Install 2-3/8" CTC, TIW, Bowen connection. 4 point stub off to PRT frame. Pull tested CTC in two stages. 10K / 21K. with crane. Swapped out e-line units. RU Pollard E-line. MU 1.375" Tools: Dual weight bars, Feed through jars, CCL. Rih to a solid tag of CTC at 10406' MD Uncorrected. Pooh without issue. Missing crossover for tubing punch run. Fly helicopter with correct crossover. MU and RIH with tubing punch. Tag top of CTC and punch coil at 10,364' corrected depth. POH and have 400# overpull. Work free with jars. POOH and confirm shots fired. Damage below shots to bha but everything recovered. MU and RIH with RCT cutting tool. 7/22/2021 Continue Eline Cutter Ops, tagged just above the TBG Punches at 10361'. Fire cutter, PU and pulling heavy. Had to Jar the tools back into the coil then POOH. Tools OOH, cutter shows a cut was made, LD AK Eline Tools Fill hole and prep to MU Spoolable Connector to pull CT OOH. Pull test to 65k, good test, slack off to 55k, install bowl & hand slips. Verify no pressure below rams, open 2-3/8" Pipe Slips. PUH to verify coil is free, pipe is moving Stop with spoolable connector above the chains. Stab injector back on the well and POOH Continue to POOH to 300'. Cycle swab and continue POOH until able to close swab. Close SSSV, Master and SSV. Break off well and make up external CTC. Pull test to 20k. Good. Stab back on well. PT QTS and pack off to 2500 psi. PT N2 line to 4000 psi. Good. PJSM with entire crew and Ops team for N2 blow down. Blow down coil reel with 1000scf/min for 30 minutes. Confirm N2 at choke manifold and MGS. Bleed off and RD N2 pump and tanks. Work boat and offload N2 pump and tanks, BHI tools, Pollard E-line unit and misc. Continue cleaning PFMS and pit system. Clamp coil and un- stab from injector with crane. Secure coil to horses head on reel. Begin RD coiled tubing injector, stuffing box and riser. Inspect BOP ram bodies. 7/23/2021 RD Yellow Jacket Pumps. RD Pason & Quadco Equipment. Flush all surface Hard & Soft line with BaraClean. Pressure wash upper PMFS. Suck out sumps to ready equipment for removal. Remove injector from jacking frame & remove pack off. Flush all high & Low pressure iron with inhibited fresh water. Fabricate shipping bar and secure coiled tubing to reel. Drain and grease choke skid. RD choke and kill hoses. Work boat and offload the following equipment. Trip tank. Mud Pumps. BOT tools and swell packers. Remaining BHI tools. Choke skid. ISO. Take on "bread basket" for hoses and misc. ND Nordic pack off assembly. QTS. Riser. Annular. Break flanges and prepare to RD remaining BOP stack. Drain and RD remaining hard line. 7/24/2021 Continue cleaning Pits. Remove welds from Jacking Frame beams. RD PRT Jacking Frame. ND BOPE & Spacer Spools. NU Production Tree. Finished cleaning pits, RD hoses and cap inlets and outlets RD hardline and softline. Remove welds and RD Mousehole. RD MGS Stack. RD Nordic hydraulic hoses and lines. ND choke and kill line 90 and flanges. 7/25/2021 Continue Demob Ops while WO Weather for work boats to unload and the dock Consolidate loads and picks for offloading. Work boat Sovereign arrives. Lift and position coiled tubing reel skid system and reel stand. Offload entire pit system. Offload PRT jacking frame. Offload ISO's. Offload misc. baskets and loads. Continue spooling and storing injector and BOP hoses. 7/26/2021 Continue Demob Ops. Waiting on Weather at the dock to offload and return, sounds like the weather should lay down later this afternoon. Stage equipment for offloading. Offloaded some equipment on a boat that had room Sovereign work boat arrives. Offload PFMS components, Mud shack and Baker MWD shack. Drilling Auto choke panels. Endeavor work boat arrives. Offload "Dance Floor" and misc equipment. Continue organizing and cleaning drill deck. 7/27/2021 Move ISO's. Skid coiled tubing reel towards crane. Pick reel and load in reel stand. Move reel, reel stand. Begin RD of skidding base. Cut welds and confirm skid base free. Sovereign attempts to pull up to platform. Boat waved off because of high winds and rough seas. Masco Endeavor also attempted to pull up to platform. Also waved off because of high winds and rough seas. Sovereign returns to OSK. Masco Endeavor waiting near Shirleyville. 7/28/2021 Continue WOW for work boat to offload equipment and clean up welds on the deck beams used to secure equipment during operations. Flew night crews off the platform, day crews still onboard to offload remaining equipment. 3 bbls OBM ran over PFMS cuttings box. Make all required notifications. Clean up deck. MU and RIH with RCT cutting tool. punch coil at 10,364' corrected depth. Pull out of hole with 5/16"e- line. E-line Anchor recovered. POOH Continue to POOH to 300' Hot tap coil and confirm 0 psi in coil. Install 2-3/8" CTC, tagged just above the TBG Punches at 10361'. Fire cutter, o MU Spoolable Connector to pull CT OOH. Vert Uncert 1sd[ft]0.005.00Start MDEnd MDSurvey Date[ft][ft]0.008000.0006/04/218000.0010200.0006/04/2110200.0010469.0007/12/21MDInclinationAzimuthTVDTVDSSNorthEastGrid EastGrid NorthLatitudeLongitudeDLSToolfaceBuild RateTurn RateVert SectMajor SemiMinor SemiVert SemiMinor AzimComments[ft][°][°][ft][ft][ft][ft][US ft][US ft][°/100ft][°][°/100ft][°/100ft][ft][ft][ft][ft][°]0.00 0.00 171.00 0.00 -105.00 0.00 0.00 263287.17 2544567.62 60°57'29.4603"N151°19'54.6774"W0.00 0 0.00 0.00 0.00 100.00 100.00 10.00 0.0075.00 0.25 171.00 75.00 -30.00 -0.16 0.03 263287.19 2544567.46 60°57'29.4587"N151°19'54.6769"W0.33 -146.283 0.33 0.00 0.11 100.00 100.00 10.09 171.00100.00 0.17 150.00 100.00 -5.00 -0.25 0.05 263287.22 2544567.37 60°57'29.4579"N151°19'54.6764"W0.44 115.5 -0.32 -84.00 0.16 100.00 100.00 10.09 168.23125.00 0.17 201.00 125.00 20.00 -0.31 0.06 263287.22 2544567.30 60°57'29.4572"N151°19'54.6763"W0.59 170.51 0.00 204.00 0.21 100.01 100.01 10.09 169.60150.00 0.08 351.00 150.00 45.00 -0.33 0.04 263287.21 2544567.29 60°57'29.4571"N151°19'54.6766"W0.97 -154.082 -0.36 600.00 0.24 100.01 100.01 10.09 352.60175.00 0.33 203.00 175.00 70.00 -0.38 0.01 263287.17 2544567.24 60°57'29.4566"N151°19'54.6772"W1.60 106.037 1.00 -592.00 0.29 100.01 100.01 10.09 178.54200.00 0.42 260.00 200.00 95.00 -0.46 -0.11 263287.05 2544567.16 60°57'29.4558"N151°19'54.6796"W1.47 169.569 0.36 228.00 0.43 100.02 100.02 10.09 192.78225.00 0.17 43.00 225.00 120.00 -0.45 -0.17 263286.99 2544567.17 60°57'29.4559"N151°19'54.6809"W2.26 -62.61 -1.00 572.00 0.46 100.02 100.02 10.09 22.21246.00 0.75 352.00 246.00 141.00 -0.29 -0.17 263286.99 2544567.33 60°57'29.4574"N151°19'54.6809"W3.13 -76.933 2.76 -242.86 0.34 100.02 100.02 10.09 17.44300.00 1.00 322.00 299.99 194.99 0.43 -0.51 263286.67 2544568.06 60°57'29.4645"N151°19'54.6877"W0.95 -28.242 0.46 -55.56 -0.02 100.03 100.03 10.09 327.62400.00 3.75 301.00 399.90 294.90 2.80 -3.85 263283.38 2544570.50 60°57'29.4879"N151°19'54.7554"W2.84 -89.761 2.75 -21.00 0.17 100.06 100.06 10.10 305.08500.00 6.25 248.00 499.56 394.56 2.45 -11.71 263275.52 2544570.30 60°57'29.4844"N151°19'54.9145"W4.99 24.445 2.50 -53.00 5.30 100.10 100.09 10.10 278.02600.00 6.50 249.00 598.94 493.94 -1.62 -22.04 263265.11 2544566.45 60°57'29.4444"N151°19'55.1237"W0.27 180 0.25 1.00 14.88 100.14 100.14 10.11 262.51700.00 6.00 249.00 698.34 593.34 -5.52 -32.20 263254.87 2544562.75 60°57'29.4059"N151°19'55.3296"W0.50 -90.497 -0.50 0.00 24.22 100.19 100.19 10.12 257.96800.00 6.00 248.00 797.80 692.80 -9.35 -41.93 263245.06 2544559.12 60°57'29.3682"N151°19'55.5265"W0.10 -170.191 0.00 -1.00 33.24 100.25 100.24 10.14 255.62900.00 4.00 243.00 897.41 792.41 -12.90 -49.88 263237.04 2544555.74 60°57'29.3333"N151°19'55.6876"W2.05 159.626 -2.00 -5.00 40.93 100.31 100.31 10.15 253.961000.00 3.25 248.00 997.21 892.21 -15.54 -55.62 263231.25 2544553.21 60°57'29.3073"N151°19'55.8038"W0.81 -33.256 -0.75 5.00 46.56 100.39 100.38 10.17 252.981100.00 6.00 232.00 1096.88 991.88 -19.82 -62.36 263224.42 2544549.07 60°57'29.2651"N151°19'55.9404"W3.01 -32.137 2.75 -16.00 54.09 100.47 100.46 10.19 250.881200.00 9.25 220.00 1195.99 1090.99 -29.20 -71.65 263214.94 2544539.88 60°57'29.1728"N151°19'56.1285"W3.60 12.346 3.25 -12.00 67.20 100.56 100.54 10.21 245.721300.00 11.00 222.00 1294.43 1189.43 -42.45 -83.20 263203.13 2544526.87 60°57'29.0423"N151°19'56.3625"W1.78 8.221 1.75 2.00 84.75 100.67 100.64 10.24 240.181400.00 12.50 223.00 1392.33 1287.33 -57.45 -96.97 263189.06 2544512.15 60°57'28.8946"N151°19'56.6412"W1.51 9.175 1.50 1.00 105.06 100.78 100.74 10.27 236.261500.00 14.00 224.00 1489.66 1384.66 -74.07 -112.75 263172.94 2544495.86 60°57'28.7309"N151°19'56.9609"W1.52 8.829 1.50 1.00 127.87 100.91 100.84 10.32 233.571600.00 15.75 225.00 1586.31 1481.31 -92.37 -130.75 263154.57 2544477.93 60°57'28.5507"N151°19'57.3254"W1.77 13.19 1.75 1.00 153.38 101.06 100.96 10.37 231.761700.00 17.00 226.00 1682.25 1577.25 -112.12 -150.87 263134.06 2544458.59 60°57'28.3562"N151°19'57.7328"W1.28 9.259 1.25 1.00 181.34 101.23 101.08 10.43 230.591800.00 19.00 227.00 1777.35 1672.35 -133.38 -173.29 263111.21 2544437.79 60°57'28.1469"N151°19'58.1869"W2.02 -50.273 2.00 1.00 211.90 101.42 101.20 10.50 229.861900.00 21.25 220.00 1871.25 1766.25 -158.37 -196.85 263087.15 2544413.29 60°57'27.9008"N151°19'58.6640"W3.29 -84.522 2.25 -7.00 246.11 101.64 101.33 10.58 228.722000.00 21.50 215.00 1964.38 1859.38 -187.27 -219.01 263064.41 2544384.85 60°57'27.6163"N151°19'59.1128"W1.84 0 0.25 -5.00 282.52 101.90 101.47 10.68 226.932100.00 22.50 215.00 2057.10 1952.10 -217.95 -240.50 263042.30 2544354.61 60°57'27.3141"N151°19'59.5479"W1.00 21.803 1.00 0.00 319.93 102.18 101.61 10.80 225.202200.00 23.50 216.00 2149.15 2044.15 -249.76 -263.19 263018.97 2544323.27 60°57'27.0009"N 151°20'0.0075"W 1.07 15.77 1.00 1.00 358.96 102.51 101.76 10.93 223.872300.00 25.00 217.00 2240.32 2135.32 -282.76 -287.63 262993.86 2544290.77 60°57'26.6759"N 151°20'0.5024"W 1.56 0 1.50 1.00 400.01 102.89 101.91 11.07 222.912400.00 27.00 217.00 2330.20 2225.20 -317.77 -314.01 262966.78 2544256.31 60°57'26.3311"N 151°20'1.0366"W 2.00 0 2.00 0.00 443.84 103.33 102.07 11.24 222.152500.00 28.75 217.00 2418.59 2313.59 -355.11 -342.15 262937.89 2544219.55 60°57'25.9634"N 151°20'1.6064"W 1.75 18.61 1.75 0.00 490.58 103.85 102.23 11.44 221.512600.00 30.25 218.00 2505.63 2400.63 -394.17 -372.13 262907.12 2544181.11 60°57'25.5788"N 151°20'2.2136"W 1.58 0 1.50 1.00 539.82 104.45 102.40 11.66 221.032700.00 31.00 218.00 2591.68 2486.68 -434.31 -403.49 262874.95 2544141.61 60°57'25.1835"N 151°20'2.8487"W 0.75 -134.789 0.75 0.00 590.76 105.14102.57 11.90 220.682800.00 30.50 217.00 2677.62 2572.62 -474.87 -434.62 262843.01 2544101.70 60°57'24.7841"N 151°20'3.4791"W 0.72 90.431 -0.50 -1.00 641.88 105.91102.75 12.16 220.342900.00 30.50 218.00 2763.78 2658.78 -515.14 -465.51 262811.30 2544062.07 60°57'24.3876"N 151°20'4.1047"W 0.51 116.739 0.00 1.00 692.63 106.77 102.93 12.44 220.053000.00 30.25 219.00 2850.06 2745.06 -554.71 -496.99 262779.03 2544023.15 60°57'23.9979"N 151°20'4.7421"W 0.56 116.911 -0.25 1.00 743.19 107.72103.12 12.73 219.913100.00 30.00 220.00 2936.55 2831.55 -593.44 -528.91 262746.33 2543985.08 60°57'23.6165"N 151°20'5.3885"W 0.56 -90.866 -0.25 1.00 793.37 108.75103.32 13.03 219.873200.00 30.00 218.00 3023.15 2918.15 -632.29 -560.37 262714.08 2543946.87 60°57'23.2339"N 151°20'6.0256"W 1.00 -180 0.00 -2.00 843.36 109.88 103.52 13.34 219.793300.00 29.75 218.00 3109.87 3004.87 -671.54 -591.04 262682.63 2543908.26 60°57'22.8474"N 151°20'6.6466"W 0.25 180 -0.25 0.00 893.17 111.10 103.73 13.67 219.653400.00 29.50 218.00 3196.79 3091.79 -710.49 -621.47 262651.41 2543869.93 60°57'22.4638"N 151°20'7.2629"W 0.25 -117.441 -0.25 0.00 942.60 112.42 103.95 14.00 219.523500.00 29.25 217.00 3283.94 3178.94 -749.41 -651.34 262620.76 2543831.63 60°57'22.0806"N 151°20'7.8676"W 0.55 -117.623 -0.25 -1.00 991.65 113.84 104.18 14.33 219.383600.00 29.00 216.00 3371.29 3266.29 -788.53 -680.29 262591.03 2543793.11 60°57'21.6953"N 151°20'8.4538"W 0.55 180 -0.25 -1.00 1040.30 115.35 104.41 14.68 219.193700.00 28.25 216.00 3459.07 3354.07 -827.29 -708.45 262562.09 2543754.93 60°57'21.3137"N 151°20'9.0240"W 0.75 180 -0.75 0.00 1088.17 116.95 104.65 15.02 218.993800.00 28.00 216.00 3547.26 3442.26 -865.42 -736.15 262533.61 2543717.37 60°57'20.9381"N 151°20'9.5851"W 0.25 180 -0.25 0.00 1135.28 118.64 104.90 15.37 218.813900.00 27.75 216.00 3635.66 3530.66 -903.25 -763.64 262505.37 2543680.11 60°57'20.5656"N151°20'10.1415"W0.25 120.403 -0.25 0.00 1182.00 120.42 105.15 15.72 218.654000.0026.75220.003724.573619.57-939.33-791.79262476.492543644.6160°57'20.2103"N151°20'10.7116"W2.090-1.004.001227.76122.27105.4116.07218.61Actual Wellpath Geographic Report - including Position UncertaintyReport by Baker HughesOperatorAreaWellpathWellbore last revised Sidetrack fromUserCalculation methodFieldFacilitySlotWellWellboreGRANITE POINT Platformslot #1-04GP 31-23L2GP 31-23L2GP 31-23L207/12/2021GP31-23 at 10200.00 MDUlricardMinimum curvature105.00 ft105.00 ftE 0.00 ftN 0.00 ftMagnetic North is 15.17 degrees East of True North2.00Std DevWA_ANC_DefnProjection SystemNorth ReferenceScaleConvergence at SlotHorizontal Reference PointVertical Reference PointMD Reference PointField Vertical ReferenceActual Datum, Orig RKB = 105 (RKB) To Facility Vertical DatumActual Datum, Orig RKB = 105 (RKB) To mean sea levelActual Datum, Orig RKB = 105 (RKB) to Mud Line at Slot (slot #1-0Section Origin XSection Origin Y07/26/21 at 11:00 using WellArchitect 6.0Hilcorp Alaska, LLCCook Inlet, Alaska (Offshore)Granite Point FieldNAD27 / TM Alaska SP, Zone 4 (5004), US feetTrue0.9999641.16 WestSlotActual Datum, Orig RKB = 105 (RKB)Actual Datum, Orig RKB = 105 (RKB)mean sea level105.00 ft218.12°included50-733-20072-62Local East Grid North LongitudeSection AzimuthSurface Position UncertaintyAPI#DeclinationEllipse Confidence LimitDatabaseGrid East[US ft]263287.17262081.75267571.89Slot LocationFacility Reference PtField Reference PtLocal North[ft]-2364.67Horiz Uncert 1sd[ft]0.0050.00[US ft]2544567.622546957.332557407.98Latitude60°57'29.4603"N60°57'52.7464"N60°59'36.7310"NPositional Uncertainty Model Log Name / CommentWellbore151°19'54.6774"W151°20'20.0745"W151°18'33.1120"W[ft]1254.04BH CoilTrak (2019) (Standard) GP 31-23L2 CoilTrak<10283-10469> GP 31-23L2OWSG Camera Based Film Gyro Multi-Shot rev1 GP-31-23PB1 CB-Film-GMS <0-8000> GP-31-23PB1OWSG Camera Based Film Gyro Multi-Shot rev1 GP-31-23 CB-Film-GMS <8100-11200> GP31-23Page 1 of 2 4100.00 27.25 220.00 3813.67 3708.67 -974.10 -820.97 262446.61 2543610.44 60°57'19.8679"N151°20'11.3025"W0.50 32.17 0.50 0.00 1273.14 124.22 105.68 16.43 218.684200.00 28.00 221.00 3902.27 3797.27 -1009.36 -851.09 262415.78 2543575.80 60°57'19.5207"N151°20'11.9123"W0.88 0 0.75 1.00 1319.46 126.31 105.95 16.79 218.774300.00 28.50 221.00 3990.36 3885.36 -1045.08 -882.14 262384.01 2543540.72 60°57'19.1689"N151°20'12.5411"W0.50 0 0.50 0.00 1366.74 128.55 106.23 17.17 218.884400.00 28.75 221.00 4078.13 3973.13 -1081.24 -913.57 262351.85 2543505.21 60°57'18.8128"N151°20'13.1775"W0.25 136.778 0.25 0.00 1414.58 130.94 106.51 17.56 218.984500.00 28.25 222.00 4166.02 4061.02 -1116.97 -945.18 262319.52 2543470.13 60°57'18.4609"N151°20'13.8177"W0.69 0 -0.50 1.00 1462.21 133.43 106.80 17.95 219.104600.00 28.25 222.00 4254.10 4149.10 -1152.15 -976.85 262287.14 2543435.60 60°57'18.1145"N151°20'14.4590"W0.00 90.44 0.00 0.00 1509.44 136.03 107.10 18.35 219.234700.00 28.25 223.00 4342.19 4237.19 -1187.04 -1008.83 262254.46 2543401.37 60°57'17.7709"N151°20'15.1064"W0.47 -90.44 0.00 1.00 1556.63 138.74 107.40 18.75 219.384800.00 28.25 222.00 4430.28 4325.28 -1221.94 -1040.81 262221.79 2543367.13 60°57'17.4272"N151°20'15.7539"W0.47 118.379 0.00 -1.00 1603.82 141.57 107.71 19.15 219.514900.00 28.00 223.00 4518.48 4413.48 -1256.70 -1072.65 262189.24 2543333.03 60°57'17.0849"N151°20'16.3987"W0.53 -137.481 -0.25 1.00 1650.82 144.52 108.03 19.55 219.645000.00 27.50 222.00 4606.98 4501.98 -1291.02 -1104.11 262157.10 2543299.35 60°57'16.7469"N151°20'17.0356"W0.68 -43.404 -0.50 -1.00 1697.24 147.54 108.35 19.95 219.765100.00 28.00 221.00 4695.47 4590.47 -1325.89 -1134.96 262125.55 2543265.11 60°57'16.4035"N151°20'17.6602"W0.68 91.324 0.50 -1.00 1743.72 150.68 108.67 20.36 219.835200.00 28.00 224.00 4783.77 4678.77 -1360.50 -1166.67 262093.14 2543231.16 60°57'16.0627"N151°20'18.3022"W1.41 43.871 0.00 3.00 1790.52 153.96 109.01 20.77 219.945300.00 28.50 225.00 4871.86 4766.86 -1394.25 -1199.84 262059.29 2543198.09 60°57'15.7303"N151°20'18.9740"W0.69 0 0.50 1.00 1837.56 157.38 109.34 21.18 220.125400.00 28.50 225.00 4959.74 4854.74 -1427.99 -1233.58 262024.87 2543165.04 60°57'15.3980"N151°20'19.6572"W0.00 62.882 0.00 0.00 1884.93 160.94 109.69 21.61 220.315500.00 28.75 226.00 5047.52 4942.52 -1461.57 -1267.75 261990.03 2543132.17 60°57'15.0673"N151°20'20.3490"W0.54 0 0.25 1.00 1932.44 164.64 110.03 22.04 220.515600.00 29.00 226.00 5135.09 5030.09 -1495.11 -1302.49 261954.62 2543099.34 60°57'14.7369"N151°20'21.0524"W0.25 -63.25 0.25 0.00 1980.27 168.48 110.39 22.47 220.715700.00 29.25 225.00 5222.45 5117.45 -1529.23 -1337.20 261919.22 2543065.94 60°57'14.4010"N151°20'21.7552"W0.55 0 0.25 -1.00 2028.54 172.47 110.74 22.91 220.895800.00 29.50 225.00 5309.59 5204.59 -1563.91 -1371.89 261883.84 2543031.97 60°57'14.0594"N151°20'22.4575"W0.25 -136.095 0.25 0.00 2077.24 176.61 111.11 23.35 221.055900.00 29.00 224.00 5396.84 5291.84 -1598.76 -1406.14 261848.89 2542997.82 60°57'13.7162"N151°20'23.1509"W0.70 44.778 -0.50 -1.00 2125.79 180.87 111.47 23.80 221.176000.00 29.50 225.00 5484.09 5379.09 -1633.61 -1440.39 261813.94 2542963.68 60°57'13.3730"N151°20'23.8444"W0.70 84.536 0.50 1.00 2174.35 185.25 111.85 24.25 221.296100.00 29.75 229.00 5571.02 5466.02 -1667.30 -1476.52 261777.13 2542930.73 60°57'13.0412"N151°20'24.5761"W1.99 -105.979 0.25 4.00 2223.16 189.77 112.22 24.71 221.496200.00 29.25 225.00 5658.07 5553.07 -1700.86 -1512.53 261740.45 2542897.92 60°57'12.7107"N151°20'25.3050"W2.03 0 -0.50 -4.00 2271.79 194.41 112.61 25.16 221.686300.00 30.00 225.00 5745.00 5640.00 -1735.81 -1547.48 261704.79 2542863.68 60°57'12.3665"N151°20'26.0127"W0.75 180 0.75 0.00 2320.86 199.19 112.99 25.62 221.806400.00 29.75 225.00 5831.71 5726.71 -1771.03 -1582.70 261668.86 2542829.18 60°57'12.0196"N151°20'26.7258"W0.25 0 -0.25 0.00 2370.31 204.13 113.39 26.09 221.906500.00 29.75 225.00 5918.53 5813.53 -1806.12 -1617.79 261633.07 2542794.82 60°57'11.6740"N151°20'27.4362"W0.00 0 0.00 0.00 2419.58 209.18 113.78 26.56 222.016600.00 30.00 225.00 6005.24 5900.24 -1841.34 -1653.01 261597.14 2542760.32 60°57'11.3272"N151°20'28.1493"W0.25 90.866 0.25 0.00 2469.03 214.36 114.19 27.03 222.106700.00 30.00 227.00 6091.84 5986.84 -1876.07 -1688.98 261560.48 2542726.33 60°57'10.9851"N151°20'28.8774"W1.00 0 0.00 2.00 2518.55 219.67 114.59 27.50 222.236800.00 30.00 227.00 6178.45 6073.45 -1910.17 -1725.54 261523.23 2542692.98 60°57'10.6493"N151°20'29.6178"W0.00 0 0.00 0.00 2567.95 225.09 115.00 27.97 222.386900.00 30.00 227.00 6265.05 6160.05 -1944.27 -1762.11 261485.98 2542659.64 60°57'10.3134"N151°20'30.3581"W0.00 180 0.00 0.00 2617.35 230.63 115.42 28.45 222.537000.00 29.75 227.00 6351.76 6246.76 -1978.24 -1798.54 261448.87 2542626.41 60°57'9.9789"N151°20'31.0957"W0.25 117.785 -0.25 0.00 2666.57 236.26 115.84 28.93 222.667100.00 29.25 229.00 6438.80 6333.80 -2011.19 -1835.13 261411.62 2542594.21 60°57'9.6544"N151°20'31.8364"W1.10 -76.576 -0.50 2.00 2715.07 241.94 116.27 29.40 222.827200.00 29.50 227.00 6525.94 6420.94 -2044.01 -1871.57 261374.52 2542562.14 60°57'9.3311"N151°20'32.5743"W1.01 136.095 0.25 -2.00 2763.39 247.71 116.70 29.87 222.977300.00 29.00 228.00 6613.19 6508.19 -2077.02 -1907.59 261337.84 2542529.87 60°57'9.0060"N151°20'33.3035"W0.70 105.387 -0.50 1.00 2811.60 253.57 117.14 30.34 223.107400.00 28.75 230.00 6700.76 6595.76 -2108.70 -1944.03 261300.76 2542498.94 60°57'8.6940"N151°20'34.0412"W1.00 -119.594 -0.25 2.00 2859.01 259.46 117.58 30.81 223.277500.00 27.75 226.00 6788.86 6683.86 -2140.34 -1979.20 261264.96 2542468.03 60°57'8.3824"N151°20'34.7534"W2.14 -135.835 -1.00 -4.00 2905.61 265.34 118.03 31.27 223.397600.00 26.00 222.00 6878.06 6773.06 -2172.80 -2010.62 261232.89 2542436.21 60°57'8.0626"N151°20'35.3894"W2.52 60.864 -1.75 -4.00 2950.55 271.09 118.49 31.71 223.417700.00 26.25 223.00 6967.84 6862.84 -2205.27 -2040.37 261202.48 2542404.36 60°57'7.7429"N151°20'35.9917"W0.51 -24.68 0.25 1.00 2994.45 276.79 118.95 32.14 223.397800.00 27.25 222.00 7057.14 6952.14 -2238.45 -2070.77 261171.42 2542371.80 60°57'7.4161"N151°20'36.6071"W1.10 43.849 1.00 -1.00 3039.33 282.70 119.41 32.58 223.377900.00 28.25 224.00 7145.64 7040.64 -2272.49 -2102.53 261138.97 2542338.41 60°57'7.0808"N151°20'37.2501"W1.37 0 1.00 2.00 3085.71 288.91 119.88 33.04 223.368000.00 29.75 224.00 7233.10 7128.10 -2307.37 -2136.21 261104.59 2542304.23 60°57'6.7374"N151°20'37.9319"W1.50 -75.533 1.50 0.00 3133.94 295.46 120.35 33.51 223.388100.00 30.50 219.00 7319.61 7214.61 -2344.94 -2169.42 261070.63 2542267.34 60°57'6.3673"N151°20'38.6042"W2.62 -86.481 0.75 -5.00 3184.00 298.87 120.59 33.78 223.388200.00 31.00 211.00 7405.58 7300.58 -2386.75 -2198.67 261040.54 2542226.13 60°57'5.9555"N151°20'39.1962"W4.12 -28.014 0.50 -8.00 3234.95 299.06 120.61 33.84 223.378300.00 32.00 210.00 7490.85 7385.85 -2431.78 -2225.18 261013.12 2542181.66 60°57'5.5121"N151°20'39.7328"W1.13 -72.398 1.00 -1.00 3286.74 299.45 120.66 33.91 223.348400.00 32.75 206.00 7575.31 7470.31 -2479.04 -2250.29 260987.06 2542134.92 60°57'5.0466"N151°20'40.2411"W2.27 29.155 0.75 -4.00 3339.42 300.06 120.76 34.00 223.288500.00 33.75 207.00 7658.94 7553.94 -2528.10 -2274.76 260961.60 2542086.36 60°57'4.5635"N151°20'40.7363"W1.14 0 1.00 1.00 3393.12 300.90 120.92 34.09 223.188600.00 35.00 207.00 7741.48 7636.48 -2578.41 -2300.39 260934.95 2542036.59 60°57'4.0680"N151°20'41.2551"W1.25 57.885 1.25 0.00 3448.52 302.01 121.13 34.19 223.058700.00 35.75 209.00 7823.02 7718.02 -2629.51 -2327.57 260906.73 2541986.05 60°57'3.5647"N151°20'41.8053"W1.38 38.574 0.75 2.00 3505.51 303.42 121.38 34.30 222.908800.00 36.50 210.00 7903.79 7798.79 -2680.82 -2356.61 260876.66 2541935.34 60°57'3.0595"N151°20'42.3930"W0.95 142.889 0.75 1.00 3563.80 305.15 121.67 34.42 222.728900.00 35.00 212.00 7984.95 7879.95 -2730.90 -2386.68 260845.58 2541885.89 60°57'2.5662"N151°20'43.0016"W1.90 156.104 -1.50 2.00 3621.76 307.17 121.95 34.56 222.529000.00 33.75 213.00 8067.48 7962.48 -2778.52 -2417.01 260814.29 2541838.89 60°57'2.0972"N151°20'43.6155"W1.37 165.284 -1.25 1.00 3677.95 309.43 122.23 34.70 222.339100.00 31.75 214.00 8151.58 8046.58 -2823.64 -2446.85 260783.54 2541794.40 60°57'1.6529"N151°20'44.2196"W2.07 65.594 -2.00 1.00 3731.87 311.86 122.49 34.85 222.149200.00 32.25 216.00 8236.39 8131.39 -2867.04 -2477.25 260752.27 2541751.62 60°57'1.2255"N151°20'44.8349"W1.17 100.175 0.50 2.00 3784.77 314.52 122.72 35.00 221.959300.00 32.00 219.00 8321.08 8216.08 -2909.22 -2509.61 260719.06 2541710.11 60°57'0.8101"N151°20'45.4899"W1.61 180 -0.25 3.00 3837.93 317.46 122.91 35.17 221.799400.00 31.75 219.00 8406.00 8301.00 -2950.26 -2542.84 260685.00 2541669.76 60°57'0.4059"N151°20'46.1625"W0.25 55.659 -0.25 0.00 3890.73 320.65 123.05 35.34 221.649500.00 32.50 221.00 8490.70 8385.70 -2990.98 -2577.02 260650.00 2541629.74 60°57'0.0048"N151°20'46.8545"W1.30 65.544 0.75 2.00 3943.87 324.14 123.18 35.52 221.509600.00 32.75 222.00 8574.92 8469.92 -3031.36 -2612.75 260613.46 2541590.10 60°56'59.6071"N151°20'47.5776"W0.59 85.114 0.25 1.00 3997.69 327.94 123.27 35.72 221.399700.00 33.00 226.00 8658.91 8553.91 -3070.38 -2650.44 260574.98 2541551.85 60°56'59.2228"N151°20'48.3406"W2.19 109.749 0.25 4.00 4051.66 332.05 123.30 35.92 221.319800.00 32.00 232.00 8743.27 8638.27 -3105.62 -2690.92 260533.80 2541517.44 60°56'58.8757"N151°20'49.1600"W3.37 98.446 -1.00 6.00 4104.37 336.34 123.21 36.12 221.329900.00 31.75 236.00 8828.20 8723.20 -3136.65 -2733.62 260490.48 2541487.29 60°56'58.5700"N151°20'50.0243"W2.13 41.436 -0.25 4.00 4155.14 340.75 123.03 36.33 221.4210000.00 33.00 238.00 8912.66 8807.66 -3165.79 -2778.53 260444.99 2541459.06 60°56'58.2829"N151°20'50.9335"W1.65 60.128 1.25 2.00 4205.79 345.41 122.84 36.55 221.5910100.00 34.00 241.00 8996.05 8891.05 -3193.78 -2826.08 260396.88 2541432.05 60°56'58.0072"N151°20'51.8961"W1.93 115.056 1.00 3.00 4257.16 350.41 122.64 36.78 221.8310200.00 33.50 243.00 9079.20 8974.20 -3219.87 -2875.12 260347.32 2541406.97 60°56'57.7502"N151°20'52.8890"W1.22 48.671 -0.50 2.00 4307.96 355.63 122.48 37.02 222.13 Tie In to GP31-2310283.00 33.91 243.83 9148.25 9043.25 -3240.48 -2916.31 260305.72 2541387.20 60°56'57.5472"N151°20'53.7228"W0.74 -62.63 0.49 1.00 4349.60 357.85 122.55 37.52 222.25 TOWS/KOP10303.70 36.99 235.00 9165.12 9060.12 -3246.60 -2926.61 260295.31 2541381.29 60°56'57.4869"N151°20'53.9312"W28.84 -14.904 14.88 -42.66 4360.77 357.85 122.56 37.53 222.25 Int Az10330.43 45.67 231.80 9185.18 9080.18 -3257.15 -2940.73 260280.97 2541371.03 60°56'57.3830"N151°20'54.2172"W33.41 -17.663 32.47 -11.97 4377.79 357.86 122.56 37.55 222.25 Int Az10330.70 45.76 231.76 9185.37 9080.37 -3257.27 -2940.89 260280.81 2541370.91 60°56'57.3818"N151°20'54.2203"W34.98 -16.536 33.33 -14.81 4377.97 357.86 122.57 37.55 222.2510360.22 55.46 228.30 9204.08 9099.08 -3271.94 -2958.31 260263.09 2541356.60 60°56'57.2373"N151°20'54.5730"W34.08 -40.701 32.86 -11.72 4400.27 357.86 122.57 37.57 222.2510383.24 60.69 223.25 9216.26 9111.26 -3285.57 -2972.29 260248.84 2541343.25 60°56'57.1030"N151°20'54.8558"W29.36 -56.615 22.72 -21.94 4419.62 357.86 122.58 37.59 222.2510413.01 65.86 215.07 9229.66 9124.66 -3306.18 -2989.02 260231.70 2541322.99 60°56'56.9000"N151°20'55.1945"W30.05 -35.225 17.37 -27.48 4446.17 357.86 122.59 37.61 222.2510433.14 70.93 211.32 9237.07 9132.07 -3321.84 -2999.25 260221.15 2541307.54 60°56'56.7458"N151°20'55.4016"W30.56 0 25.19 -18.63 4464.81 357.87 122.60 37.62 222.2510469.0070.93211.329248.789143.78-3350.80-3016.87260202.952541278.9560°56'56.4606"N151°20'55.7581"W0.00N/A0.000.004498.46357.87122.6037.65222.25Projection to TDPage 2 of 2 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 or fax to 907 564-4422. Received By: Date: Date: 8/16/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 31-23L2 (PTD 221-020) FINAL LWD FORMATION EVALUATION LOGS (07/07/2021 to 07/13/2021) x Multiple Propagation Resistivity/Gamma ray (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. 37' (6HW Received By: 08/19/2021 By Abby Bell at 4:17 pm, Aug 18, 2021 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, SuLte 400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, GP 31-23 L2 Hilcorp Alaska, LLC Permit to Drill Number: 221-020 Surface Location: 2365' FNL, 1253' FWL, Sec 13, T10N, R12W, SM, AK Bottomhole Location: 2056' FSL, 1714' FWL, Sec 23, T10N, R12W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. The permit is for a new wellbore segment of existing well Permit Number 167-084, API Number 50-733-20072-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of June, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.24 10:49:31 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11.Well Name and Number: Bond No. 3. Address: 6.Proposed Depth: 12. Field/Pool(s): MD: 13,929' TVD: 10,955' 4a. Location of Well (Governmental Section): 7.Property Designation: Surface: Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 105' 15.Distance to Nearest Well Open Surface: x-263287 y- 2544567 Zone-4 N/A to Same Pool: 0' to GP 31-23 16. Deviated wells: Kickoff depth: 10,279 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 83 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 4-1/4" 2-7/8" 6.5# L-80 STL 3,649' 10,280' 9,146' 13,929' 10,955' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): N/A TVD 603' 3,665' 7,287' 9,894' Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number: 50- Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Sr Pet Eng Sr Pet Geo Sr Res Eng GL / BF Elevation above MSL (ft): 9,860' - 11,176' 8,794' - 9,878' 8,062'8,062' See cover letter for other requirements. Perforation Depth MD (ft): 11,196' 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 3,329' Perforation Depth TVD (ft): Commission Use Only 2435 sx Effect. Depth MD (ft): Authorized Signature: 7" 800 sx 1182 sx Surface Production Liner Casing 11,147' Intermediate 3,933' 9-5/8" 670 sx 604' 3,933'13-3/8" 11,147' 9,855' Effect. Depth TVD (ft): Conductor/Structural 18"604' 11,200'9,897' Length 5476 Total Depth MD (ft): Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 3584 517' FNL, 1828' FEL, Sec 23, T10N, R12W, SM, AK 2056' FSL, 1714' FWL, Sec 23, T10N, R12W, SM, AK LOCI 19-001 5089 GP 31-23 L2 Granite Point Field Middle Kenai Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 2365' FNL, 1253' FWL, Sec 13, T10N, R12W, SM, AK ADL018761 022224484 1710' to nearest unit boundary 6/3/2021 Authorized Name: Monty Myers Authorized Title: Drilling Manager Sean Mclaughlin Sean.Mclaughlin@hilcorp.com 777-8401 18. Casing Program: Top - Setting Depth - BottomSpecifications Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 6.18.2021 By Samantha Carlisle at 7:56 am, Jun 21, 2021 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.06.18 14:51:44 -08'00' Monty M Myers A variance to 20 AAC 25.005(c)(4)(A) is approved for MPSP = 3584 psi, based on a 2/3 column of gas, 1/3 column oil. Daily reports to be submitted to AOGCC every day. A variance to 20 AAC 25.036(c)(2)(A)(iii) is approved. See conditions in attached procedure. REVISED SFD 6/21/2021 3584 A variance to 20 AAC 25.036(c)(4)(A)(ii) is approved. See conditions in attached procedure. 50-733-20072-62-00 10,062 BJM 6/23/2021 10,062 221-020 BOP test to 4000 psi. Annular test to 3500 psi. DSR-6/21/21SFD 6/21/2021 SFD 6/21/2021 6/24/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.24 10:50:09 -08'00' To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin Drilling Engineer Date: June 18, 2021 Re: Granite Point Platform 31-23 L2 Permit to Drill Request Approval is requested for drilling a second lateral from well GP31-23 with Coiled Tubing Drilling equipment on or around June 2021. Proposed plan for GP31-23 production add lateral: After running liner in L1 (221-018), a second whipstock will be set in the C5 interval at 10,279’. The second lateral (L2) will be completed with a 2-7/8” slotted liner brought back to the tubing. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: 1. Reference GP31-23 L1 PTD 221-018 Rig Work: 2. Run 4-1/2” x 7” whipstock and set 10,279’ and 15 LOHS. a. KWF will be in the wellbore from the L1 liner run 3.Mill L2 3.80” single string window plus 10’ of rathole. a.Mill window with 0.6 deg motor 4.Drill and complete the L2 lateral a.Drill with bicenter bit (4.25”) i.Target constant bottom hole pressure of 9.5 ppg for entire sidetrack ii.Near TD there is a small possibility that past injection, from 1973, may have elevated the pressure in the area to 10.5 ppg EMW. It is unknown if the pressure is trapped or has dissipated. Drill with caution through the area utilizing real time BHP to monitor pressure. If necessary, use MPD choke to elevate EWM as necessary to maintain overbalance. b. Swap to 7.4 ppm OBM prior to drilling c. 35 deg/100’ build section – 150’ d.12 deg/100’ lateral section - 3,500’ e.Planned TD 13,929’ f.After TD and on the last trip out of hole lay in KWF in preparation for the liner run g.Perform no flow test prior to laying down drilling BHA 5.Run 2-7/8” slotted liner with liner top placed in the tubing tail a.Place swell packers and solid pipe across potential water zones 6.After releasing from the liner swap the well over to diesel a. Expect 600 psi on the wellhead after the fluid swap. Post Rig: 1.V: Tree work as necessary 2. S: Install LTP lay in KWF in preparation for the liner run gg p use MPD choke to elevate EWM as necessary to maintain overbalance. p ppg small possibility that past injection, from 1973, may have elevated thepy pressure in the area to 10.5 ppg EMW. Managed Pressure Drilling: Due to concerns with wellbore stability managed pressure drilling techniques will be employed on this lateral. The intent is to provide constant bottom hole pressure by using 7.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to improve hole stability. Applying annular friction and choke pressure also allows use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure is located between the WC choke manifold and the mud pits and will be independent of the WC choke. Deployment of the BHA under trapped wellbore pressure will be necessary to maintain constant wellbore pressure. A TRSSSV in the completion will be used to maintain wellbore pressure when handling BHA’s. During BHA handling, the BHA must be able to be lifted above a functioning SSV or the blind rams. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling. The following is a range in scenarios expected: x Expected reservoir pressure in L2: 4047 psi (8.1 ppg) at 12,200’ MD – 9742’ TVD MPD Pressure at the GP31-23 L2 Window (10,284’ MD - 9149’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,520 psi 4,520 psi 9.5 B Annular friction - ECD (psi/ft)929 psi 0 psi 0.09 C Mud Hydrostatic (ppg)3,521 psi 3,521 psi 7.4 B+C 4,450 psi 3,521 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 70 psi 999 psi Target BHP at window and deeper x High side case in L2: 10.5 ppg at the window Pumps On Pumps Off A Target BHP at Window (ppg)4,995 psi 4,995 psi 10.5 B Annular friction - ECD (psi/ft)926 psi 0 psi 0.09 C Mud Hydrostatic (ppg)3,521 psi 3,521 psi 7.4 B+C 4,447 psi 3,521 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 548 psi 1,474 psi Target BHP at window and deeper High side case in L2: 10.5 ppg at the window gq 7.4 ppg drilling fluid Expected reservoir pressure in L2: 4047 psi (8.1 ppg) Operation Details: Reservoir Pressure: x The maximum potential reservoir pressure while drilling will occur ~13,175’ MD. Past water injection may have elevated pressure in this area and it is unknown if it has dissipated. The pressure may be as high as 5476psi (10.5 ppf EMW). x See Alternative MASP variance request below Mud Program: x Drilling: Minimum MW of 7.4 ppg OBM for drilling. Managed pressure used to maintain constant BHP. x KWF will be stored on location. The tankage will contain 1.2 wellbore volumes of KWF to exceed the maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring. x Sufficient weighting material will be on location to elevate to KWF to 10.5 ppg if necessary. x Completion: KWF to be used for liner deployment. Disposal: x All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results Hole Size: x 4.25” bicenter hole for entirety of the sidetrack. Liner Program: x 2-7/8”, 6.5#, L-80 STL slotted liner, swell packers and solid liner across water zones x No Cement Well Control: x 1.2 wellbore volumes of KWF will be on location at all times during drilling operations. x 4 Ram BOP diagram is attached. MPD and BHA deployment using the TRSSSV is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,000 psi. x The annular preventer will be tested to 250 psi and 3,500 psi. x An X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Directional: x Directional plan attached. Maximum planned hole angle is 83°. x Inclination at kick off point is 34°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 1,710’ x Distance to nearest well within pool – 0’ (GP 31-23) Logging: x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x No perforating, slotted liner. Anti-Collision Failures: x No AC failures. Hazards: x Granite Point is not considered a high H2S platform. The highest recorded H2S well on the platform was from gas lift (2ppm). Drilling sidetracks from GP31-23 has a low H2S risk. x Medium lost circulation risk. MPD used to minimize overbalance while drilling. j pressure may be as highp as 5476psi (10.5 ppf EMW) f 7.4 ppg OBM for drilling. maximum potential reservoir pressure while drilling will occur ~13,175’ MD. Variance Requests: x 20 AAC 25.005(c)(4)(A) - The calculated MASP for this wellbore when completely evacuated to gas is 4470 psi. However, for Granite Point Operations, the assumption is that the well can never flow 100% gas. Using an historical alternative Granite Point MASP yields 3584 psi which assumes that 2/3 of the wellbore is evacuated to gas and 1/3 to 7.0 ppg reservoir fluid. o Calculated MASP using fluid properties yields a MASP of 2251 psi. x A variance to 20 AAC 25.036(c)(4)(A)(ii) is requested for the following clause: A BOPE assembly must include a hydraulic actuating system with an accumulator pump system consisting of one or more pumps with independent primary and secondary power sources. The following conditions must be met: o BOP closing times must meet the requirements of API 16D 3rd edition, 6.2.3, for both the accumulator pump (without the aid of the accumulator) and accumulator (without the aid of the pump). o If the accumulator pump power supply fails, the well will be secured immediately, and all downhole work will cease until the accumulator pump is fully operational. o The accumulator system useable volume (30 gallons – approximately 3 times that required to close all BOP rams and annular) and BOP stack are the same as the proposed system submitted to the AOGCC (attached to this PTD). x Coiled Tubing BHA deployment using a closed Sub-Surface Safety Valve (SSSV) to contain wellbore pressure where hydrostatic pressure exerted by the drilling fluid is less than the reservoir pressure. A variance to 20 AAC 25.036(c)(2)(A)(iii) is requested with the following conditions: o The BHA lifting equipment must be capable of lifting the full length of the BHA above a remotely controlled surface safety valve (SSV) that is installed in the vertical run of the tree. o The remotely controlled SSV must be functional during BHA deployment and removal. A fuseable cap or other device designed to lock open the SSV during CT operations must be removed before the BHA is deployed or removed from the well. o SSSV must be tested with a 10-minute flow check prior to each BHA deployment, with visual confirmation of no flow from the returns stream pipework. Sean McLaughlin CC: Well File CTD Engineer Cody Dinger 907-223-6784 Variance approved. Same conditions as for GP31-23 L1 PTD 221--018. Verified calcs based on 5476 psi @ 10062' TVD. SSV to be function pressure tested to at least MASP of 3584 psi during the first BOP test on this lateral. bjm Variance approved with additional condition. Variance approved for 2/3 gas column, 1/3 7.0 ppg reservoir fluid column. See email attached for justification.-bjm _____________________________________________________________________________________ Revised By: CJD 2/23/2021 PROPOSED Granite Point Platform Well: GP 31-23/ L1 / L1-01/ L2 / L2-01 Last Completed: Future PTD: TBD TD = 11,200’ (MD) / TD =9,886’(TVD) 18” Top of 2-7/8” Liner @15,731’ 7” 1 3 4 10 9 8 7 9-5/8 ” 6 PBTD = 11,147’(MD) / PBTD =9,855’(TVD) 2 Top of Whipstock @11,016’ 5 13-3/8” Top of Whipstock @10,279’ KB Elev.: 105’ / Water Depth.: 75’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 18" Conductor - N/A Surface 604' 13-3/8" Surface 61 / J-55 / BTC 12.515 Surface 3,933’ 9-5/8" Intermediate 40, 43.5 / N-80, S-95 / BTC, LTC, STC 8.755 Surface 8,062’ 7” Liner 29 / P-110 / X-Line 6.184 7,867’ 11,196’ L1: 2-7/8” Slotted Liner 6.5 / L-80 / STL 2.441 ±11,025’ ±13,886’ L1-01: 2-7/8” Slotted Liner 6.5 / L-80 / STL 2.441 ±11,160’ ±13,206’ L2: 2-7/8” Slotted Liner 6.5 / L-80 / STL 2.441 ±10,280’ ±13,929’ L2-01: 2-7/8” Slotted Liner 6.5 / L-80 / STL 2.441 ±9,850’ ±12,790’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958 Surface ±10,180’ GP 31-23 L2 TD = 13,929’ (MD) GP 31-23 L1 TD = 13,450’ (MD) Swell Packers Sliding Sleeve Liner Top Packer ! 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"!2 ! 4 1 5 67 ' & 5 8 &/ 5 5 $ &/ 9 $ #: $ ' ;& 4 8 8 & 5 5 42 151/5 6 5 1& Well GP31-23 Date Jacking frame Deck Flow check line to trip tank 7-1/16" Combi Kill Line Choke Line 7-1/16" Combi Drill Deck 4-1/16" Tree x 7-1/16" Riser 18' top tubing spool to drill deck Swab MPD line in Master IA OA Wellhead Room 4 Ram BOP Schematic 18-May-21 Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8"x3-1/2" VBR SSV Manual Choke HYD Choke April 12, 2021 Sean McLaughlin Hilcorp Alaska, LLC 3800 Centerpoint Dr. #1400 Anchorage, AK 99503 E-mail: sean.mclaughlin@hilcorp.com RE: CTU 1 – Accumulator volume calculations Dear Mr. McLaughlin: As requested, please find below the accumulator calculations for the coiled tubing unit planned for the Granite Point CTD program. The accumulator should have sufficient usable hydraulic fluid volume (with pumps inoperative) to close one annular-type preventer, all ram-type preventers from a full-open position, and open one HCR valve. After closing one annular preventer, all ram-type preventers, and opening one HCR valve, the remaining pressure shall be 200 psi or more above the minimum recommended precharge pressure. Hydril 7-1/16” Annular 3.86 gal to close TOT 7-1/16” Blind/Shear 3.50 gal to close TOT 7-1/16” Pipe /Slip 0.70 gal to close TOT 7-1/16” VBR 0.70 gal to close TOT 7-1/16” Pipe /Slip 0.70 gal to close CIW 3 1/8” HCR 0.61 gal to open Total fluid volume required 10.07 gal Four 15-gallon (1,000 psi precharge) accumulator bottles are incorporated in the coiled tubing unit. Total usable volume while maintaining 200 psi above the precharge pressure is 30 gallons. Regards, Udo Cassee General Manager Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole 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 name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements 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 (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. X -733-20072-00-00X Granite Point NOTE: In March 2021, AOGCC revised the Permit to Drill application form (Form 10-401). Please use that revised form for future submittals. Copies are available on AOGCC's website. 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