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Home My WebLink About221-1017. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-106A Replace LTP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 221-101 50-029-23055-01-00 8645 Conductor Surface Intermediate Production Liner 6560 80 2698 6914 1825 8070 20" 7-5/8" 5-1/2" x 3-1/2" 2-3/8" 6558 29 - 109 28 - 2726 26 - 6940 6820 - 8645 29 - 109 28 - 2653 26 - 6586 6465 - 6560 None 470 4790 4990 11780 8070 1490 6890 7000 11200 8005 - 8620 3-1/2" 9.2# L-80 24 - 6684 6569 - 6561 Structural No Packer No SSSV Installed None None Torin Roschinger Operations Manager Tyson Shriver Tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, BOREALIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239 24 - 6329 N/A N/A 368 673 10292 5611 1357 1249 1500 1100 500 340 N/A 13b. Pools active after work:Borealis Oil No SSSV Installed No Packer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.11.21 13:38:25 -09'00' Torin Roschinger (4662) By Grace Christianson at 1:05 pm, Nov 22, 2023 DSR-11/29/23WCB 3-14-2024 RBDMS 112823 JSB ACTIVITY DATE SUMMARY 11/12/2023 ***WELL FLOWING ON ARRIVAL***(drift/set 1.781 rx-plug) HES-046, TRVL FROM N-PAD TO L-PAD, MISU, HOLD FOR WEATHER 11/13/2023 ***CONT WSR FROM 11/12/13***(drift/set 1.781 rx-plug) HES-046 WEATHER HOLD/RIG UP DRIFT W/ 1.75 BRUSH, 1.75" SAMPLE BAILER BRUSH R-NIP @ 6,790' SLM, DEVIATE OUT @ 7081' SLM SET 1.781" RX-PLUG @ 6790' SLM PERFORM DRAWDOWN TEST W/ PAD OP DOWN FLOW LINE - BLEED WELL DOWN TO 340 PSI (see log) RAN 2 3/8" GR (dogless) WITH 1.781" EQUALIZING PRONG TO EQUALIZE 1.781" RR PLUG @ 6790' SLM / 6,814' MD RAN 2 3/8" GR ATTEMPT TO PULL RR PLUG @ 6790' SLM / 6,814' MD (sheard) PULL 1.781" RX-PLUG IN NS MONO-PAK LTP @ 6,790' SLM / 6,814' MD ***CONT WSR ON 11/14/23*** 11/14/2023 ***CONT WSR FROM 11/13/23***(pull ltp, b&f, drift, set ltp) RAN 3-1/2" GS, S/D @ 6,782' SLM, UNABLE TO WORK DEEPER OR LATCH NS MONO-PAK LTP @ 6,814' SLM (-24 ft corr from 1.781" plug) DRIFT/BRUSH W/ 3-1/2" BRUSH, 2.80" GAUGE RING TO 6,788' SLM (see log) RAN 2.71" OLD STYLE SPEAR S/D & PLANT SPEAR IN NS MONO-PAK LTP @ 6,780' SLM RAN 2.68" CENTRALIZER WITH 2 7/8" GS ( 1/4" STEEL PIN) TO PULL LINER TOP PACKER@ 6780' SLM JAR UP AND PULL LINER TOP PACKER. POOH. STAND-BY FOR LRS AND DIESEL TO ARRIVE ON LOCATION TO DO BRUSH AND FLUSH. RAN 3 1/2" WIRE BRUSH, 3'- 1 1/4" STEM,2 7/8" WIRE BRUSH, 2" CENTRALIZER TO PERFORM BRUSH AND FLUSH FROM 6798' SLM TO 6000' SLM. PUMP 80 BBL'S OF HOT DEISEL. DRIFT W/ 35KB UPPER PKR & 3 1/2" PTSA DRIFT WITH 3 TT PINS S/D @ 6,786' SLM (tt-pins sheared good indicaiton ring on no-go) RIH W/ 350-272 NS- MONO-PAK LTP-2' PUP-PTSA W/ 1.781" RX-PLUG (2.72" max od, 1.81" id, 1.781" min id, 13.09' oal). ***CONT WSR ON 11/15/23*** 11/14/2023 T/I/O=1380/710/470 Assist S-Line (BRUSH & FLUSH) Pump into TBG w/ 3 bbls 60/40, 80 bbls 180* Diesel. while S-Line brushed TBG. FWHP=190/730/520 11/15/2023 T/I/O = 300/750/450. Temp = SI. T & IA FL (SL request). ALP = 1700 psi, SI @ CV. T FL @ 50' (0.4 bbls). IA FL @ 6521' (Sta #2 SO, 74 bbls). SL in control of well upon departure. WV = C. SV, SSV, MV = O. IA & OA = OTG. 14:30 Daily Report of Well Operations PBU L-106A Daily Report of Well Operations PBU L-106A 11/15/2023 ***CONT WSR FROM 11/14/23***(set ltp) SET 350-272 NS- MONO-PAK LTP-2' PUP-PTSA W/ 1.781" RX-PLUG (2.72" max od, 1.81" id, 1.781" min id, 13.09' oal). IN DEP SLV @ 6,820' MD LRS ATTEMPT 2500 PSI PRESSURE TEST AGAINST LTP (fail, see lrs log - 20 bbls away) RAN 2-3/8" GS, LATCH 1.781" RX-PLUG, PULL NS MONO-PAK LTP @ 6,785' SLM (see log - ltp did not set, good ring on no-go) NS REP - PICKS UP LTP FOR INSPECTION SET 350-272 NS- MONO-PAK LTP-2' PUP-PTSA W/ 1.781" RX-PLUG (2.72" max od, 1.81" id, 1.781" min id, 13.09' oal). IN DEP SLV @ 6,820' MD LRS CONDUCTS FAILING PRESSURE TEST (0.1 bpm leak rate, see lrs log) RAN 2 3/8" GR W/ 1.781" EQ-PRONG, PULL 1.781" RR PLUG @ 6795' SLM. RAN 3-1/2" LTTP W/ 2.25" SEAL ASYM, S/D IN NS MONO-PAK LTP @ 6,773' SLM ATTEMPT TO PRESSURE TEST TO 2500 (consistently loosing 50 psi/min, see log) ***CONT WSR ON 11/16/23*** 11/15/2023 T/I/O=300/0/0 Assist S-Line (PROFILE MODIFICATION) Pump 20 bbls Diesel into TBG to pressure to 2500 PSI. MIT-T FAILED to 2500 PSI. Established LLR of 0.1 BPM for 10 min 11/15/2023 T/I/O = 288/738/479. Temp - SI. Assist SL with pressure test. Pumped 20 bbls DSL, TBG did not pressure up. SL continued to trouble shoot. SL in control of well upon departure. FWHP's = 237/727/464 11/16/2023 T/I/O 350/800/450 Temp= S/I (TFS unit 4 assist SL with D&D hole finder) Pumped 17 bbls of Crude down TBG to Assist SL with D&D Hole finder.See log for Details. Slick Line in control of well upon departure. FWHP= 250/800/450 11/16/2023 ***CONT WSR FROM 11/15/23*** PULL 3-1/2" LTTP FROM NS MONO-PAK LTP @ 6,777 RAN 3-1/2" X-SELECTIVE TEST TOOL, TAG LTP @ 6,772' SLM PT X-NIPS & CMD- SS (see log, -35' corr off all nips) RAN 3-1/2" D&D HOLE FINDER TO NS MONO-PAK LTP @ 6,780' SLM, CONDUCT STOPS PER PRGM (see log) RAN 3 1/2" D AND D HOLE FINDER TO BELOW SSSV NIPLE (2.813") @ 2272' SLM.TEST TO 1500 PSI X 30 MINS. TEST GOOD. ***SECURE WELL, DEPART LOCATION*** 11/17/2023 ***JOB CONTINUED FROM NOVEMBER 16TH 2023*** SET 3 1/2" WHIDDON @ 6781' SLM PULLED INT-DOME FROM STA 1 3363' MD PULLED INT-OGLV FROM STA 2 6521' md SET INT- DOME VALVE-20/64"3663' MD. SET INT-OGLV-22/64" STA 2 @ 6521' MD. PULL WHIDDON CATCHER ***WELL LEFT S/I ON DEPARTURE SET 350-272 NS- MONO-PAK LTP-2' PUP-PTSA W/ 1.781" RX-PLUG (2.72" max od, 1.81" id, 1.781" min id, 13.09' oal). IN DEP SLV @ 6,820' MD DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23055-01-00Well Name/No.PRUDHOE BAY UN BORE L-106ACompletion Status1-OILCompletion Date3/5/2022Permit to Drill2211010OperatorHilcorp North Slope, LLCMD8645TVD6560Current Status1-OIL8/19/2022UICNoWell 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/DataTypeLogScaleDF4/4/20226799 8645 Electronic Data Set, Filename: PBU L-106A GAMMA RES.las36440EDDigital DataDF4/4/20225 10000 Electronic Data Set, Filename: PBU L-106A_PWD Log Run 1.las36440EDDigital DataDF4/4/202218 10000 Electronic Data Set, Filename: PBU L-106A_PWD Log Run 2.las36440EDDigital DataDF4/4/202248 10000 Electronic Data Set, Filename: PBU L-106A_PWD Log Run 3.las36440EDDigital DataDF4/4/202221 7206 Electronic Data Set, Filename: PBU L-106A_PWD Log Run 4.las36440EDDigital DataDF4/4/202248 7475 Electronic Data Set, Filename: PBU L-106A_PWD Log Run 5.las36440EDDigital DataDF4/4/202224 7981 Electronic Data Set, Filename: PBU L-106A_PWD Log Run 6.las36440EDDigital DataDF4/4/202233 8647 Electronic Data Set, Filename: PBU L-106A_PWD Log Run 7.las36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A GAMMA RES.ASC36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_PWD Log Run 1.ASC36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_PWD Log Run 2.ASC36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_PWD Log Run 3.ASC36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_PWD Log Run 4.ASC36440EDDigital DataFriday, August 19, 2022AOGCC Page 1 of 4PBU L-106A GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23055-01-00Well Name/No.PRUDHOE BAY UN BORE L-106ACompletion Status1-OILCompletion Date3/5/2022Permit to Drill2211010OperatorHilcorp North Slope, LLCMD8645TVD6560Current Status1-OIL8/19/2022UICNoDF4/4/2022 Electronic File: PBU L-106A_PWD Log Run 5.ASC36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_PWD Log Run 6.ASC36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_PWD Log Run 7.ASC36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 2MD Final Log.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 2TVDSS Final Log.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 5MD Final Log.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 5TVDSS Final Log.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 01 PWD.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 02 PWD.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 03 PWD.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 04 PWD.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 05 PWD.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 06 PWD.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 07 PWD.cgm36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 2MD Final Log.PDF36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 2TVDSS Final Log.PDF36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 5MD Final Log.PDF36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 5TVDSS Final Log.PDF36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 01 PWD.pdf36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 02 PWD.pdf36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 03 PWD.pdf36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 04 PWD.pdf36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 05 PWD.pdf36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 06 PWD.PDF36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 07 PWD.pdf36440EDDigital DataFriday, August 19, 2022AOGCC Page 2 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23055-01-00Well Name/No.PRUDHOE BAY UN BORE L-106ACompletion Status1-OILCompletion Date3/5/2022Permit to Drill2211010OperatorHilcorp North Slope, LLCMD8645TVD6560Current Status1-OIL8/19/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud 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:3/5/2022Release Date:11/30/2021DF4/4/2022 Electronic File: PBU L-106A 2MD Final Log.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 2TVDSS Final Log.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 5MD Final Log.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A 5TVDSS Final Log.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 01 PWD.cgm.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 02 PWD.cgm.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 03 PWD.cgm.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 04 PWD.cgm.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 05 PWD.cgm.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 06 PWD.cgm.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A Run 07 PWD.cgm.tif36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_Definitive Surveys.pdf36440EDDigital DataDF4/4/2022 Electronic File: PBU L-106A_Definitive Surveys.xlsx36440EDDigital DataFriday, August 19, 2022AOGCC Page 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23055-01-00Well Name/No.PRUDHOE BAY UN BORE L-106ACompletion Status1-OILCompletion Date3/5/2022Permit to Drill2211010OperatorHilcorp North Slope, LLCMD8645TVD6560Current Status1-OIL8/19/2022UICNoComments:Compliance Reviewed By:Date:Friday, 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WŽƐƚͲdWƌŽŐƌĂŵ >ͲϭϬϲ Wd͗ϮϮϭͲϭϬϭ dĞƐƚĞƌƐ^ůŽǁĞĂŶƵƉWƌŽĐĞĚƵƌĞ͗ ϭ͘ WKWƚŚĞǁĞůůƚŽ^ZǁŝƚŚ ϭͲϭ͘ϱDD^&>ŝĨƚŐĂƐĂƚŵŝŶŝŵƵŵĐŚŽŬĞ͕ĂĚũƵƐƚ'>ƌĂƚĞĂƐŶĞĐĞƐƐĂƌǇƚŽ ĞůŝŵŝŶĂƚĞƐůƵŐŐŝŶŐ͘&ůŽǁƚŚĞŝŶŝƚŝĂůƌĞƚƵƌŶƐƚŽƚŚĞĨůŽǁůŝŶĞĂƐůŽŶŐĂƐƚŚĞƐŚĂŬĞͲŽƵƚƐŵĞĞƚƚŚĞƌĞƚƵƌŶĞĚ ĨůƵŝĚͬƐŽůŝĚƐŵĂŶĂŐĞŵĞŶƚŐƵŝĚĞůŝŶĞƐ͘ Ϯ͘ >ŝŵŝƚĨůŽǁƚŽϱϬϬďƉĚ ϯ͘ /ĨƐŽůŝĚƐĂƌĞфϭй͕ĂĨƚĞƌϭ͘ϱǁĞůůďŽƌĞǀŽůƵŵĞƐ;ϭϮϬ ďďůƐͿŝŶĐƌĞĂƐĞƚŚĞƉƌŽĚƵĐƚŝŽŶƌĂƚĞƚŽϳϱϬ>W͘ ϰ͘ &ůŽǁďŽƚƚŽŵƐƵƉĂŶĚƐĂŵƉůĞĨŽƌƐŽůŝĚƐƉƌŽĚƵĐƚŝŽŶ͘/ĨƐŽůŝĚƐĂ ƌĞƐƚŝůůďĞůŽǁϭй͕ ŝŶĐƌĞĂƐĞĨůŽǁƚŽϭϬϬϬ &W͘ ϱ͘ &ůŽǁ ďŽƚƚŽŵƐƵƉĂŶĚƐĂŵƉůĞĨŽƌƐŽůŝĚƐƉƌŽĚƵĐƚŝŽŶ͘/ĨƐŽůŝĚƐĂƌ ĞƐƚŝůůďĞůŽǁϭйĐŽŶƚŝŶƵĞƚŽŝŶĐƌĞĂƐĞƚŚĞ ĨůŽǁƌĂƚĞŝŶϮϱϬWŝŶĐƌĞŵĞŶƚƐ͘dŚĞŽďũĞĐƚŝǀĞŝƐƚŽĂĐŚŝĞǀĞŵĂǆŝŵƵŵĚƌĂǁĚŽǁŶ͘tĂƚĐŚƌĞƚƵƌŶƐĂŶĚ ĚŽŶŽƚĐŽŶƚŝŶƵĞƚŽŽƉĞŶĐŚŽŬĞŝĨƐŽůŝĚƐхϭй͖ĂůůŽǁǁĞůůĐůĞĂŶƵƉďĞĨŽƌĞĐŚŽŬĞŝƐŽƉĞŶĞĚĨƵƌƚŚĞƌ͘ ϲ͘ KŶĐĞĂƚ&K͕ƐƚĂďŝůŝǌĞƚŚĞǁĞůůĨŽƌϰŚƌƐ͘KďƚĂŝŶĂŶ ϴŚƌǁĞůůƚĞƐƚ͘ WŽƐƚͲdWƌŽŐƌĂŵ >ͲϭϬϲ Wd͗ϮϮϭͲϭϬϭ dŝĞͲ/Ŷ>ŽŐ ;ƚŽďĞƐƵƉƉůŝĞĚĂĨƚĞƌĚƌŝůůŝŶŐůĂƚĞƌĂůͿ dƵďĞŵŽǀĞ͗ ĂƚĞ͗ &ĞďƌƵĂƌǇ ϴ͕ϮϬϮϮ ^ƵďũĞĐƚ͗ >ͲϭϬϲ &ƌĂĐƚƵƌĞ^ƚŝŵƵůĂƚŝŽŶ &ƌŽŵ͗ ĂǀŝĚtĂŐĞƐ K͗;ϵϬϳͿϱϲϰͲϱϬϬϲ ͗;ϳϭϯͿ ϯϴϬͲϵϴϯϲ dŽ͗ K' ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ ϯͬϮϬͬϮϬϮϭ 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ϮͬϮͬϮϬϮϮ͗ ŽŶŽĐŽWŚŝůůŝƉƐ ǆǆŽŶDŽďŝů ŚĞǀƌŽŶ ĞƉĂƌƚŵĞŶƚŽĨEĂƚƵƌĂůZĞƐŽƵƌĐĞƐ WůĂƚ/ĚĞŶƚŝĨǇŝŶŐtĞůůƐ ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϮͿ͗ WůĂƚŽĨǁĞůůƐǁŝƚŚŝŶŽŶĞͲŚĂůĨŵŝůĞŽĨ ƉůĂŶŶĞĚ>ͲϭϬϲ ǁĞůůďŽƌĞ ƚƌĂũĞĐƚŽƌǇ͘ >ŝƐƚŽĨǁĞůůƐŝŶWůĂƚϮϬϮϱ͘Ϯϴϯ͕ Ă͕ Ϯ ǆĞŵƉƚŝŽŶĨŽƌ&ƌĞƐŚǁĂƚĞƌƋƵŝĨĞƌƐ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϯͲ ϰͿ͗ tĞůů >ͲϭϬϲ ŝƐŝŶƚŚĞtĞƐƚKƉĞƌĂƚŝŶŐƌĞĂŽĨWƌƵĚŚŽĞĂǇ͘WĞƌƋƵŝĨĞƌǆĞŵƉƚŝŽŶKƌĚĞƌEŽ͘ϭĚĂƚĞĚ:ƵůǇ ϭϭ͕ϭϵϴϲǁŚĞƌĞ^ƚĂŶĚĂƌĚůĂƐŬĂWƌŽĚƵĐƚŝŽŶŽŵƉĂŶǇƌĞƋƵĞƐƚĞĚƚŚĞůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶ ŽŵŵŝƐƐŝŽŶƚŽŝƐƐƵĞĂŶŽƌĚĞƌĞǆĞŵƉƚŝŶŐƚŚŽƐĞƉŽƌƚŝŽŶƐŽĨĂůůĂƋƵŝĨĞƌƐůǇŝŶŐĚŝƌĞĐƚůǇďĞůŽǁƚŚĞtĞƐƚĞƌŶ KƉĞƌĂƚŝŶŐƌĞĂĂŶĚ<WĂĚƌĞĂŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĨŽƌůĂƐƐ///ŶũĞĐƚŝŽŶĂĐƚŝǀŝƚŝĞƐ͘&ŝŶĚŝŶŐƐϭͲ ϰ ƐƚĂƚĞ͗ ϭ͘ dŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞtĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐ ŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĚŽŶŽƚĐƵƌƌĞŶƚůǇƐĞƌǀĞĂƐĂƐŽƵƌĐĞŽĨĚƌŝŶŬŝŶŐǁĂƚĞƌ͘ Ϯ͘ dŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞtĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐ ŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĂƌĞƐŝƚƵĂƚĞĚĂƚĂĚĞƉƚŚĂŶĚůŽĐĂƚŝŽŶƚŚĂƚŵĂŬĞƐƌĞĐŽǀĞƌǇŽĨǁĂƚĞƌĨŽƌ ĚƌŝŶŬŝŶŐǁĂƚĞƌƉƵƌƉŽƐĞƐĞĐŽŶŽŵŝĐĂůůǇŝŵƉƌĂĐƚŝĐĂďůĞ͘ ϯ͘ dŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞtĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐ ŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚĂƌĞƌĞƉŽƌƚĞĚƚŽŚĂǀĞƚŽƚĂůĚŝƐƐŽůǀĞĚƐŽůŝĚƐĐŽŶƚĞŶƚŽĨϳϬϬϬŵŐͬ/Žƌ ŵŽƌĞ͘ ϰ͘ ǇůĞƚƚĞƌŽĨ:ƵůǇϭ͕ϭϵϴϲ͕WͲ ZĞŐŝŽŶϭϬĂĚǀŝƐĞƐƚŚĂƚƚŚĞĂƋƵŝĨĞƌƐŽĐĐƵƌƌŝŶŐďĞŶĞĂƚŚƚŚĞ tĞƐƚĞƌŶKƉĞƌĂƚŝŶŐĂŶĚ<ƉĂĚĂƌĞĂƐŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚƋƵĂůŝĨǇĨŽƌĞǆĞŵƉƚŝŽŶ͘/ƚŝƐ ĐŽŶƐŝĚĞƌĞĚƚŽďĞĂŵŝŶŽƌĞǆĞŵƉƚŝŽŶĂŶĚĂŶŽŶͲƐƵďƐƚĂŶƚŝĂůƉƌŽŐƌĂŵƌĞǀŝƐŝŽŶŶŽƚƌĞƋƵŝƌŝŶŐŶŽƚŝĐĞ ŝŶƚŚĞ&ĞĚĞƌĂůZĞŐŝƐƚƌĂƌ͘ WĞƌƚŚĞĂďŽǀĞĨŝŶĚŝŶŐƐ͕ΗdŚŽƐĞƉŽƌƚŝŽŶƐŽĨĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐůǇŝŶŐĚŝƌĞĐƚůǇďĞůŽǁƚŚĞtĞƐƚĞƌŶ KƉĞƌĂƚŝŶŐĂŶĚ<WĂĚƌĞĂƐŽĨƚŚĞWƌƵĚŚŽĞĂǇhŶŝƚƋƵĂůŝĨǇĂƐĞǆĞŵƉƚĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐƵŶĚĞƌϮϬ Ϯϱ͘ϰϰϬΗƚŚƵƐĂůůŽǁŝŶŐWĞǆĞŵƉƚŝŽŶĨƌŽŵϮϬϮϱ͘Ϯϴϯ͕Ă͕ϯͲ ϰǁŚŝĐŚƌĞƋƵŝƌĞŝĚĞŶƚŝĨŝĐĂƚŝŽŶŽĨ ĨƌĞƐŚǁĂƚĞƌĂƋƵŝĨĞƌƐĂŶĚĞƐƚĂďůŝƐŚŝŶŐĂƉůĂŶĨŽƌďĂƐĞͲǁĂƚĞƌƐĂŵƉůŝŶŐ͘ ĞƚĂŝůĞĚĂƐŝŶŐĂŶĚĞŵĞŶƚ/ŶĨŽƌŵĂƚŝŽŶ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϱͲ ϲͿ͗ tĞůů >ͲϭϬϲ ǁĂƐƐƉƵĚĚĞĚ ϬϭͬϬϯͬϮϬϬϮ ϵͲϳͬϴ͟ŚŽůĞǁĂƐĚƌŝůůĞĚǁŝƚŚŽƵƚŝŶĐŝĚĞŶƚĂŶĚĂĨĞǁƚŝŐŚƚƐƉŽƚƐ ƚŽϮϳϰϱ͛ǁŚĞƌĞĂƐŽŶŝĐůŽŐǁĂƐƌƵŶƚŽ ĞǀĂůƵĂƚĞŚǇĚƌĂƚĞƐŝŶƚŚĞĂƌĞĂ͘ϳͲϱͬϴ͟>ϴϬĐĂƐŝŶŐǁĂƐƌƵŶĂŶĚĐĞŵĞŶƚĞĚĂƚϮϳϮϲ͛ǁŝƚŚϮϴϰďďůƐůĞĂĚ 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;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϳͿ͗ dĂďůĞϭͶ dƵďŝŶŐĂŶĚWƌŽĚƵĐƚŝŽŶĂƐŝŶŐWƌĞƐƐƵƌĞdĞƐƚŝŶŐdƵďŝŶŐ ĂƚĞ dƵďŝŶŐWƌĞƐƐƵƌĞ ;ƉƐŝͿ WƌŽĚƵĐƚŝŽŶĂƐŝŶŐWƌĞƐƐƵƌĞ ;ƉƐŝͿ ŝĨĨĞƌĞŶƚŝĂůWƌĞƐƐƵƌĞ ;ƉƐŝͿ dϰϱϬϬ Ϭ ϰϱϬϬ dϮϬϬϬ ϰϱϬϬ ϮϱϬϬϰϱϬϬ ϰϱϬϬ ĐĐƵƌĂƚĞWƌĞƐƐƵƌĞZĂƚŝŶŐƐŽĨdƵďƵůĂƌƐĂŶĚ^ĐŚĞŵĂƚŝĐ ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϴͿ͗ &ŝŐƵƌĞϭͶ WƌŽƉŽƐĞĚ tĞůůďŽƌĞƐĐŚĞŵĂƚŝĐĨŽƌǁĞůů >ͲϭϬϲĂ dĂďůĞϮͶ dƵďƵůĂƌZĂƚŝŶŐƐ ^ŝǌĞͬEĂŵĞ tĞŝŐŚƚ 'ƌĂĚĞ ŽŶŶĞĐƚŝŽŶ /ƵƌƐƚ͕ƉƐŝ ŽůůĂƉƐĞ͕ƉƐŝ ϳͲϱͬϴ͟^ƵƌĨĂĐĞ Ϯϵ͘ϳη >ͲϴϬ dϲ͘ϴϳϱ͟ϭϬ͕ϭϲϬ ϭϬ͕ϱϰϬ ϱͲϭͬϮ͟WƌŽĚƵĐƚŝŽŶĂƐŝŶŐ ϭϱ͘ϱη >ͲϴϬ dϰ͘ϵϱϬ͟ϱϲϵϬ ϰϰϳϬ ϯͲϭͬϮ͟WƌŽĚƵĐƚŝŽŶ>ŝŶĞƌ ϵ͘ϯη >ͲϴϬ E^d Ϯ͘ϵϵϮ͟ϭϬ͕ϭϲϬ ϭϬ͕ϱϰϬ ϯͲϭͬϮ͟WƌŽĚƵĐƚŝŽŶdƵďŝŶŐ ϵ͘ϯη ϭϯƌϴϬ sĂŵdŽƉ ϯ͘ϵϱϴ͟ϭϬ͕ϭϲϬ ϭϬ͕ϱϰϬ ϮͲϯͬϴ͟WƌŽĚƵĐƚŝŽŶ>ŝŶĞƌ ϰ͘ϳη >ͲϴϬ ,Ǉϱϭϭ ϭ͘ϵϵϱ ϭϭ͕ϮϬϬ ϭϭ͕ϳϴϬ tĞůůŚĞĂĚ &D ŵĂŶƵĨĂĐƚƵƌĞĚǁĞůůŚĞĂĚ͕ƌĂƚĞĚƚŽϱ͕ϬϬϬƉƐŝ͘ dƵďŝŶŐŚĞĂĚĂĚĂƉƚŽƌ͗ϭϭΗϱ͕ϬϬϬƉƐŝǆϯͲ ϭͬϴΗϱ͕ϬϬϬƉƐŝ dƵďŝŶŐ^ƉŽŽů͗ϭϭΗϱ͕ϬϬϬƉƐŝǁͬϮͲϭͬϭϲΗƐŝĚĞŽƵƚůĞƚƐ ĂƐŝŶŐ^ƉŽŽů͗ϭϭΗϱ͕ϬϬϬƉƐŝǁͬϮͲϭͬϭϲΗƐŝĚĞŽƵƚůĞƚƐ dƌĞĞ͗ĂŵĞƌŽŶϯͲϭͬϴΗϱ͕ϬϬϬƉƐŝ 'ĞŽůŽŐŝĐĂů&ƌĂĐ/ŶĨŽƌŵĂƚŝŽŶ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϵͿ͗ dĂďůĞϯͶ 'ĞŽůŽŐŝĐĂů/ŶĨŽƌŵĂƚŝŽŶ&ŽƌŵĂƚŝŽŶ &ŽƌŵĂƚŝŽŶ DdŽƉ DŽƚ dsƐƐdŽƉ dsƐƐŽƚ ds dŚŝĐŬŶĞƐƐ &ƌĂĐ 'ƌĂĚ ƉƐŝͬĨƚ >ŝƚŚ͘ ĞƐĐ͘ d,Zϲϱϲϴ ϲϳϵϱ Ͳϲϭϯϱ Ͳϲϯϲϭ ϮϮϲ ^ŚĂůĞ d<>ϲϳϵϱ ϲϵϭϱ Ͳϲϯϲϭ Ͳϲϰϴϭ ϭϮϬ ^ŚĂůĞ d<hW ϲϵϭϱ ϲϵϯϬ Ͳϲϰϴϭ Ͳϲϰϵϳ ϭϲ ^ŚĂůĞ d<ϰ ϲϵϯϬ ϲϵϰϵ Ͳϲϰϵϳ Ͳϲϱϭϱ ϭϴ ^ŚĂůĞ d<ϯϲϵϰϵ ϲϵϱϳ Ͳϲϱϭϱ ͲϲϱϮϯ ϴ ^^ d<ϯϲϵϱϳ ϲϵϳϮ ͲϲϱϮϯ Ͳϲϱϯϴ ϭϱ ^^ d<ϯϲϵϳϮ ϲϵϵϳ Ͳϲϱϯϴ Ͳϲϱϲϯ Ϯϱ ^^ d<ϯϲϵϵϳ ϳϬϭϬ Ͳϲϱϲϯ Ͳϲϱϳϳ ϭϰ ^^ d<ϮϳϬϭϬ ϳϬϭϵ Ͳϲϱϳϳ Ͳϲϱϴϲ ϵ ^^ d<ϮϳϬϭϵ ϳϬϮϳ Ͳϲϱϴϲ Ͳϲϱϵϯ ϳ ^^ d<ϮϳϬϮϳ ϳϬϯϲ Ͳϲϱϵϯ ͲϲϲϬϮ ϵ ^^ d<ϮϳϬϯϲ ϳϬϰϰ ͲϲϲϬϮ ͲϲϲϭϬ ϴ ^^ d<ϮϳϬϰϰ ϳϬϱϬ ͲϲϲϭϬ Ͳϲϲϭϳ ϳ ^^ d<ϭϳϬϱϬ ϳϬϲϭ Ͳϲϲϭϳ ͲϲϲϮϴ ϭϭ ^^ d<ϭϳϬϲϭ ϳϬϴϲ ͲϲϲϮϴ ͲϲϲϱϮ Ϯϰ ^^ d<ϭϳϬϴϲ ϳϭϬϬ ͲϲϲϱϮ Ͳϲϲϲϲ ϭϰ ^^ >hͬƐŝůƚƐ ϳϭϬϬ ϳϮϯϲ Ͳϲϲϲϲ ͲϲϴϬϮ ϭϯϲ ^ŝůƚƐͬ^^ d<ϲ ϳϮϯϲ ϳϮϰϮ ͲϲϴϬϮ ͲϲϴϬϴ ϲ ^ŝůƚƐͬ^^ d<ϱ ϳϮϰϮ ϳϮϱϮ ͲϲϴϬϴ Ͳϲϴϭϴ ϭϬ ^ŝůƚƐͬ^^ d<ϰ ϳϮϱϮ ϳϯϭϱ Ͳϲϴϭϴ Ͳϲϴϴϭ ϲϯ ^ŝůƚƐͬ^^ dD>s ϳϯϭϱ Ͳϲϴϴϭ ^ŝůƚƐͬ^^ Ύ dŽƉƐĂƌĞĨƌŽŵƚŚĞ >ͲϭϬϲ >ŽĐĂƚŝŽŶŽĨtĞůůƐ͕DĞĐŚĂŶŝĐĂů/ŶĨŽƌŵĂƚŝŽŶĂŶĚ&ĂƵůƚƐ ;ϮϬϮϱ͘Ϯϴϯ͕Ă͕ϭϬͲ ϭϭͿ͗ &ŝŐƵƌĞϯďͶ WůĂƚŽĨǁĞůůƐǁŝƚŚŝŶŽŶĞͲŚĂůĨŵŝůĞŽĨ ƉůĂŶŶĞĚ>ͲϭϬϲ ǁĞůůďŽƌĞ ƌĞƐĞƌǀŽŝƌ ƚƌĂũĞĐƚŽƌǇĂŶĚůŽĐĂƚŝŽŶŽĨĨĂƵůƚƐ͘dŚĞďůƵĞ ůŝŶĞŝŶĚŝĐĂƚĞƐƚŚĞĂƉƉƌŽǆŝŵĂƚĞĨƌĂĐƚƵƌĞůĞŶŐƚŚĂŶĚŽƌŝĞŶƚĂƚŝŽŶ ŽĨƚŚĞĨƌĂĐ͛Ɛ͘ 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Ɖƌŝůϭϭ͕ϮϬϮϮ;ĂͿ;ϵͿ;Ϳ&ƌĂĐƚƵƌŝŶŐĂŶĚĐŽŶĨŝŶŝŶŐǌŽŶĞƐ͗ůŝƚŚŽůŽŐŝĐĚĞƐĐƌŝƉƚŝŽŶĨŽƌĞĂĐŚǌŽŶĞ;ĂͿ;ϵͿ;Ϳ'ĞŽůŽŐŝĐĂůŶĂŵĞŽĨĞĂĐŚǌŽŶĞ;ĂͿ;ϵͿ;ͿĂŶĚ;ĂͿ;ϵͿ;ͿDĞĂƐƵƌĞĚĂŶĚƚƌƵĞǀĞƌƚŝĐĂůĚĞƉƚŚƐ;ĂͿ;ϵͿ;Ϳ&ƌĂĐƚƵƌĞƉƌĞƐƐƵƌĞĨŽƌĞĂĐŚǌŽŶĞhƉƉĞƌĐŽŶĨŝŶŝŶŐǌŽŶĞƐ͗hƉƉĞƌĐŽŶĨŝŶĞŵĞŶƚǁŝůůďĞƉƌŽǀŝĚĞĚďǇƚŚĞ<ƵƉĂƌƵŬ͕<ĂůƵďŝŬ͕WĞďďůĞƐŚĂůĞ͕ĂŶĚ,ZƐŚĂůĞĂŶĚƐŝůƚƐƚŽŶĞŝŶƚĞƌǀĂůƐ͕ǁŚŝĐŚŚĂǀĞĂŶĂŐŐƌĞŐĂƚĞƚŚŝĐŬŶĞƐƐŽĨĂďŽƵƚϯϲϮƚƌƵĞǀĞƌƚŝĐĂůĨĞĞƚ͘dŚĞĨƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚĨŽƌƚŚĞƐĞƐƚƌĂƚĂŝƐĞǆƉĞĐƚĞĚƚŽďĞĂďŽƵƚϭϯ͘ϱƉƉŐDt͘&ƌĂĐƚƵƌŝŶŐŽŶĞ͗<ƵƉĂƌƵŬƐĂŶĚƐƚŽŶĞǁŝƚŚĂŶĞǆƉĞĐƚĞĚĨƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚŽĨĂďŽƵƚϬ͘ϲϬƚŽϬ͘ϲϲƉƐŝͬĨƚ;ϭϭ͘ϲƚŽϭϮ͘ϳƉƉŐDtͿ͘>ŽǁĞƌĐŽŶĨŝŶŝŶŐǌŽŶĞƐ͗>ŽǁĞƌĐŽŶĨŝŶĞŵĞŶƚǁŝůůďĞƉƌŽǀŝĚĞĚďǇƚŚĞDŝůƵǀĞĂĐŚĂŶĚ<ŝŶŐĂŬƐŚĂůĞŝŶƚĞƌǀĂůƐ͕ǁŝƚŚĂŶĂŐŐƌĞŐĂƚĞƚŚŝĐŬŶĞƐƐŽĨĂďŽƵƚϭ͕ϴϱϬƚƌƵĞǀĞƌƚŝĐĂůĨĞĞƚŝŶƚŚŝƐĂƌĞĂ͘dŚĞĨƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚĨŽƌƚŚĞƐĞƐƚƌĂƚĂŝƐĞǆƉĞĐƚĞĚƚŽďĞĂďŽƵƚϬ͘ϳϮƉƐŝͬĨƚ;ϭϯ͘ϵƉƉŐDtͿ͘>ϬϯͬϬϮͬϮϬϮϮ;ĂͿ;ϭϬͿ>ŽĐĂƚŝŽŶ͕ŽƌŝĞŶƚĂƚŝŽŶ͕ƌĞƉŽƌƚŽŶŵĞĐŚĂŶŝĐĂůĐŽŶĚŝƚŝŽŶŽĨĞĂĐŚǁĞůůϭϯǁĞůůƐŝŶĐůƵĚŝŶŐƚŚĞ>ͲϭϬϲŵŽƚŚĞƌďŽƌĞŝĚĞŶƚŝĨŝĞĚǁŝƚŚĐĞŵĞŶƚdKĚĂƚĂƉƌŽǀŝĚĞĚĨŽƌǁĞůůƐŝŶĐůƵĚŝŶŐWΘ͛ĚǁĞůůƐ͘tϯͬϯͬϮϬϮϮ;ĂͿ;ϭϭͿ^ƵĨĨŝĐŝĞŶƚŝŶĨŽƌŵĂƚŝŽŶƚŽĚĞƚĞƌŵŝŶĞǁĞůůƐǁŝůůŶŽƚŝŶƚĞƌĨĞƌĞǁŝƚŚĐŽŶƚĂŝŶŵĞŶƚǁŝƚŚŝŶЪŵŝůĞzĞƐ͘EŝŶĞǁĞůůƐ͕ŝŶĐůƵĚŝŶŐŽŶĞƌĞĚƌŝůů͕ĂŶĚƚǁŽƉůƵŐďĂĐŬƐŝŶƚĞƌĐĞƉƚƚŚĞĐŽŶĨŝŶĞŵĞŶƚŝŶƚĞƌǀĂůƐǁŝƚŚŝŶĂŽŶĞͲŚĂůĨŵŝůĞƌĂĚŝƵƐŽĨWh>ͲϭϬϲ͘dŚĞŶĞĂƌĞƐƚǁĞůů͕>ͲϬϯ͕ůŝĞƐŽǀĞƌϯϱϬĨĞĞƚƚŽƚŚĞƐŽƵƚŚŽĨƚŚĞĨƌĂĐƚƵƌŝŶŐŝŶƚĞƌǀĂůŝŶ>ͲϭϬϲ͘dŚĞƉƌŝŶĐŝƉĂůƐƚƌĞƐƐĚŝƌĞĐƚŝŽŶŝƐŽƌŝĞŶƚĞĚϯϬͲϰϱĚĞŐƐ͘tŽĨEŝŶƚŚŝƐĂƌĞĂ͕ĂŶĚƚŚĞŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐǁŝůůĚĞǀĞůŽƉĂůŽŶŐƚŚŝƐƐĂŵĞEtĚŝƌĞĐƚŝŽŶ͕ƉĞƌƉĞŶĚŝĐƵůĂƌƚŽƚŚĞǁĞůůďŽƌĞ͘/ƚŝƐŚŝŐŚůǇƵŶůŝŬĞůǇƚŚĂƚ>ͲϬϯŽƌŽƚŚĞƌŶĞĂƌďǇǁĞůůƐǁŝůůŝŶƚĞƌĨĞƌĞǁŝƚŚĐŽŶƚĂŝŶŵĞŶƚŽĨĨƌĂĐƚƵƌŝŶŐĨůƵŝĚƐǁŝƚŚŝŶƚŚĞ<ƵƉĂƌƵŬƌĞƐĞƌǀŽŝƌ͘>ϬϯͬϬϮͬϮϬϮϮ;ĂͿ;ϭϭͿ&ĂƵůƚƐĂŶĚĨƌĂĐƚƵƌĞƐ͕>ŽĐĂƚŝŽŶ͕ŽƌŝĞŶƚĂƚŝŽŶ;ĂͿ;ϭϭͿ&ĂƵůƚƐĂŶĚĨƌĂĐƚƵƌĞƐ͕^ƵĨĨŝĐŝĞŶƚzĞƐ͘dŚĞŽƉĞƌĂƚŽƌŚĂƐŝĚĞŶƚŝĨŝĞĚĞŝŐŚƚƉŽƐƐŝďůĞĨĂƵůƚƐŽŶƐĞŝƐŵŝĐůŝŶĞƐǁŝƚŚŝŶŽŶĞͲŚĂůĨŵŝůĞƌĂĚŝƵƐŽĨƚŚĞǁĞůůďŽƌĞ͘ĂĐŚŽĨƚŚĞƐĞĨĂƵůƚƐƚĞƌŵŝŶĂƚĞǁŝƚŚŝŶŽƌďĞůŽǁƚŚĞŽǀĞƌůǇŝŶŐŽůǀŝůůĞ͕^ĐŚƌĂĚĞƌůƵĨĨŽƌ^ĂŐĂǀĂŶŝƌŬƚŽŬĨŽƌŵĂƚŝŽŶƐ͘dŚĞƐĞ>ϬϯͬϬϯͬϮϬϮϮ 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;ĂͿ;ϭϮͿ;ͿƐƚŝŵĂƚĞĚǀŽůƵŵĞWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘ϮϬϬϴďďůƚŽƚĂůĚŝƌƚǇǀŽů͘ŝŶĐůƵĚŝŶŐϴϲďďůĨƌĞĞǌĞƉƌŽƚĞĐƚ͘ϭϴϲůďƚŽƚĂůƉƌŽƉƉĂŶƚtϯͬϯͬϮϬϮϮ;ĂͿ;ϭϮͿ;ͿĚĚŝƚŝǀĞƐ͗ŶĂŵĞƐ͕ƉƵƌƉŽƐĞƐ͕ĐŽŶĐĞŶƚƌĂƚŝŽŶƐWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϯͬϯͬϮϬϮϮ;ĂͿ;ϭϮͿ;ͿŚĞŵŝĐĂůŶĂŵĞĂŶĚ^ŶƵŵďĞƌŽĨĞĂĐŚWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘^ĐŚůƵŵďĞƌŐĞƌĚŝƐĐůŽƐƵƌĞƉƌŽǀŝĚĞĚ͘tϯͬϯͬϮϬϮϮ;ĂͿ;ϭϮͿ;Ϳ/ŶĞƌƚƐƵďƐƚĂŶĐĞƐ͕ǁĞŝŐŚƚŽƌǀŽůƵŵĞŽĨĞĂĐŚWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϯͬϯͬϮϬϮϮ;ĂͿ;ϭϮͿ;ͿDĂǆŝŵƵŵƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞǁŝƚŚƐƵƉƉŽƌƚŝŶŐŝŶĨŽƚŽĚĞƚĞƌŵŝŶĞĂƉƉƌŽƉƌŝĂƚĞŶĞƐƐĨŽƌƉƌŽŐƌĂŵ^ŝŵƵůĂƚŝŽŶ;͘tĂŐĞƐŶŽƚ^ĐŚůƵŵďĞƌŐĞƌƉƌŝŶƚŽƵƚͿƐŚŽǁƐŵĂǆĂŶƚŝĐŝƉĂƚĞĚƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞϲϬϬϬƉƐŝ͘ZĞĐĞŝǀĞĚĂĚĚŝƚŝŽŶĂůĨƌĂĐŵŽĚĞůŝŶĨŽƌŵĂƚŝŽŶ͘tĂŐĞƐϮͬϮϱĨŽƌ>ͲϭϭϲĨŽƌǀĞƌŝĨŝĐĂƚŝŽŶŽĨŵĞƚŚŽĚĞƚĐ͘͘DĂǆ͘ϳϵϬϬƉƐŝĂůůŽǁĂďůĞƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞ͘DĂǆƉƌĞƐƐƵƌĞŝƐϳϭϬϬƉƐŝƚŽϳϱϬϬƉƐŝƚŽWƵŵƉƐŚƵƚĚŽǁŶ͘tŝƚŚϯϵϬϬƉƐŝďĂĐŬƉƌĞƐƐƵƌĞ/;/ƉŽƉŽĨĨƐĞƚϰϮϬϬƉƐŝͿ͕ŵĂǆƚƵďŝŶŐĚŝĨĨĞƌĞŶƚŝĂůƐŚŽƵůĚďĞϯϲϬϬƉƐŝtϯͬϯͬϮϬϮϮ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚWh>ͲϭϬϲ;WdEŽ͘ϮϮϭͲϭϬϭ͖^ƵŶĚƌǇEŽ͘ϯϮϮͲϬϲϭͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϲ 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Ɖƌŝůϭϭ͕ϮϬϮϮ;ĨͿ^ƵƌĨĂĐĞĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐDŽŶŝƚŽƌĞĚǁŝƚŚŐĂƵŐĞĂŶĚƉƌĞƐƐƵƌĞƌĞůŝĞĨĚĞǀŝĐĞ/WZsƐĞƚĂƚϯϱϬϬƉƐŝ͘^ƵƌĨĂĐĞĂŶŶƵůƵƐŽƉĞŶ͘&ƌĂĐƉƌĞƐƐƵƌĞƐĐŽŶƚŝŶƵŽƵƐůǇŵŽŶŝƚŽƌĞĚ͘tϮͬϮϯͬϮϬϮϮ;ŐͿŶŶƵůƵƐƉƌĞƐƐƵƌĞŵŽŶŝƚŽƌŝŶŐΘŶŽƚŝĨŝĐĂƚŝŽŶϱϬϬƉƐŝĐƌŝƚĞƌŝĂƵƌŝŶŐŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶƐ͕ĂůůĂŶŶƵůƵƐƉƌĞƐƐƵƌĞƐŵƵƐƚďĞĐŽŶƚŝŶƵŽƵƐůǇŵŽŶŝƚŽƌĞĚĂŶĚƌĞĐŽƌĚĞĚ͘/ĨĂƚĂŶǇƚŝŵĞĚƵƌŝŶŐŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶƐƚŚĞĂŶŶƵůƵƐƉƌĞƐƐƵƌĞŝŶĐƌĞĂƐĞƐŵŽƌĞƚŚĂŶϱϬϬƉƐŝŐĂďŽǀĞƚŚŽƐĞĂŶƚŝĐŝƉĂƚĞĚŝŶĐƌĞĂƐĞƐĐĂƵƐĞĚďǇƉƌĞƐƐƵƌĞŽƌƚŚĞƌŵĂůƚƌĂŶƐĨĞƌ͕ƚŚĞŽƉĞƌĂƚŽƌƐŚĂůů͗tϮͬϮϯͬϮϬϮϮ ;ŐͿ;ϭͿEŽƚŝĨǇK'ǁŝƚŚŝŶϮϰŚŽƵƌƐ ;ŐͿ;ϮͿŽƌƌĞĐƚŝǀĞĂĐƚŝŽŶŽƌƐƵƌǀĞŝůůĂŶĐĞ ;ŐͿ;ϯͿ^ƵŶĚƌǇƚŽK';ŚͿ^ƵŶĚƌǇZĞƉŽƌƚ ;ŝͿZĞƉŽƌƚŝŶŐ ;ŝͿ;ϭͿ&ƌĂĐ&ŽĐƵƐZĞƉŽƌƚŝŶŐ;ŝͿ;ϮͿK'ZĞƉŽƌƚŝŶŐ͗ƉƌŝŶƚĞĚΘĞůĞĐƚƌŽŶŝĐ;ũͿWŽƐƚͲĨƌĂĐǁĂƚĞƌƐĂŵƉůŝŶŐƉůĂŶEŽƚƌĞƋƵŝƌĞĚ;ƐĞĞ^ĞĐƚŝŽŶ;ĂͿ;ϯͿ͕ĂďŽǀĞͿ͕;ŬͿŽŶĨŝĚĞŶƚŝĂůŝŶĨŽƌŵĂƚŝŽŶůĞĂƌůǇŵĂƌŬĞĚĂŶĚƐƉĞĐŝĨŝĐĨĂĐƚƐƐƵƉƉŽƌƚŝŶŐŶŽŶĚŝƐĐůŽƐƵƌĞŽŶĨŝĚĞŶƚŝĂůĞǆƉůŽƌĂƚŽƌǇǁĞůů͘;ůͿsĂƌŝĂŶĐĞƐƌĞƋƵĞƐƚĞĚDŽĚŝĨŝĐĂƚŝŽŶƐŽĨĚĞĂĚůŝŶĞƐ͕ƌĞƋƵĞƐƚƐĨŽƌǀĂƌŝĂŶĐĞƐŽƌǁĂŝǀĞƌƐEŽƉůĂŶĨŽƌƉŽƐƚĨƌĂĐƚƵƌĞǁĂƚĞƌǁĞůůĂŶĂůǇƐŝƐ͘ŽŵŵŝƐƐŝŽŶŵĂǇƌĞƋƵŝƌĞƚŚŝƐĚĞƉĞŶĚŝŶŐŽŶƉĞƌĨŽƌŵĂŶĐĞŽĨƚŚĞĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶ͘tĞƐƚĂƐƚ David Douglas Hilcorp North Slope, 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: Hilcorp North Slope, LLC Date: 04/04/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU L-106A PTD: 221-101 API: 50-029-23055-01-00 FINAL LWD FORMATION EVALUATION LOGS (02/21/2022 to 02/27/2022) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Final Definitive Directional Surveys SFTP Transfer - Data Folders: Please include current contact information if different from above. 221-101 T36440 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.04.04 15:11:46 -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:Rixse, Melvin G (OGC) To:Trevor Hyatt Cc:AOGCC Records (CED sponsored) Subject:20220224 1601 APPROVAL TO PERFORATE PBU L-106A - PTD: 221-101 (Perforate with CDR2) Date:Thursday, February 24, 2022 5:02:07 PM Trevor, Hilcorp is approved to perforate PBU L-106A as described in your procedure below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Wednesday, February 23, 2022 1:42 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: HAK PBU L-106A - PTD: 221-101 (Perforate with CDR2) Mel, The original L-106A perforation plan was to utilize the post rig extended add perf procedure on service coil. With that practice not being an option currently, we would like to perforate up to 250’ on the rig after we run liner and cement. We will perforate under PTD: 221-101 See below for L-106A Perf Plan: 1. Run liner to TD 2. Cement liner with cementing BHA 3. Circulate wellbore to KWF and flow check to confirm wellbore fluid is overbalanced to the formation. 4. Trip out of hole and flow check. Lay down cementing BHA 5. Make up ~250’ of 1.56” perf guns, 6 SPF, 60 deg phasing. a. Deploy guns on 1” CSH and Coil b. 2” safety joint with crossovers will be available while handling perf guns and 1” CSH 6. Perforate wellbore per plan and pull out of hole. a. Ensure fluid level is at surface b. Flow check wellbore before laying down perf guns 7. Nozzle run to freeze protect well 8. RDMO Let me know what you think and if you need anything else from us to perform this operation with CDR2. Thank you for your time and consideration. Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:PTD221-101, Fracturing Sundry 322-061, Clarifications Date:Monday, February 14, 2022 4:33:28 PM From: Brodie Wages <David.Wages@hilcorp.com> Sent: Monday, February 14, 2022 4:24 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] PTD221-101, Fracturing Sundry 322-061, Clarifications Hi Mel, 1. L was a fat finger, this was meant to be just the MIT-IA 2. This is a pressure test of the tubing yes, but at the same time it will pressure test the liner lap. It will not be an official MIT as we know we already have tubing integrity, we are only looking to evaluate the liner x 3-1/2” lap. If this test fails, we will install a liner top packer. 3. We are MIT’ing today, target pressures remain 4500 psi, the time of this email, I know the MIT-T passed and we were working on the MIT-IA this morning. David “Brodie” Wages Ops Engineer C: 713.380.9836 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, February 14, 2022 4:17 PM To: Brodie Wages <David.Wages@hilcorp.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: [EXTERNAL] PTD221-101, Fracturing Sundry 322-061, Clarifications Brodie, Clarifications questions: 1. I am not familiar with the acronym MIT-IAL. What does the ‘L’ stand for? 2. Fullbore: you mention testing the ‘wellbore’. Is that an MIT-T to 4000 psi. 3. You mention ‘Planned MITs’. When? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Chris Wallace The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU L-106A Hilcorp North Slope, LLC Permit to Drill Number: 221-101 Surface Location: 2420' FSL, 3559' FWL, Sec. 34, T12N, R11E, UM, AK Bottomhole Location: 2450' FSL, 235' FEL, Sec. 34, T12N, R11E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this ___ day of November, 2021. 30 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.30 11:28:16 -09'00' 1a. Contact Name:Trevor Hyatt Contact Email:trevor.hyatt@hilcorp.comAuthorized Name: Monty Myers Authorized Title:Drilling Manager Authorized Signature: Contact Phone:777-8396 Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Drill Type of Work: Redrill 5 Lateral 1b.Proposed Well Class:Exploratory - Gas 5 Service - WAG 5 1c. Specify if well is proposed for: Development - Oil Service - Winj Multiple Zone Exploratory - Oil Gas Hydrates Geothermal Hilcorp North Slope, LLC Bond No. 107205344 11.Well Name and Number: PBU L-106A TVD:8840'6558' 12. Field/Pool(s): PRUDHOE BAY, BOREALIS OIL MD: ADL 028239 00-001 February 1, 2022 4a. Surface: Top of Productive Horizon: Total Depth: 2420' FSL, 3559' FWL, Sec. 34, T12N, R11E, UM, AK 2544' FSL, 1802' FEL, Sec. 34, T12N, R11E, UM, AK 2450' FSL, 235' FEL, Sec. 34, T12N, R11E, UM, AK Kickoff Depth: 6938 feet Maximum Hole Angle: 114 degrees Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole:Surface:3633 2983 17.Deviated wells:16. Surface: x-y- Zone -583357 5978143 4 10. KB Elevation above MSL: GL Elevation above MSL: feet feet 79.22' 50.4' 15.Distance to Nearest Well Open to Same Pool: Cement Quantity, c.f. or sacks MD Casing Program: 6910'6556' 19.PRESENT WELL CONDITION SUMMARY Production 80 260 sx Arctic Set (Approx.) 7455 7100 7338 7338 6984 None 29 - 109 Surface 359 sx AS Lite, 134 sx Class 'G' 6576 - 6640 Seabed Report Drilling Fluid Program 5 20 AAC 25.050 requirements Shallow Hazard Analysis 5 Commission Use Only 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: Samples req'd: Yes No H2S measures Yes No Spacing exception req'd: Yes No Mud log req'd: Yes No Directional svy req'd: Yes No Inclination-only svy req'd: Yes No Other: Date: Address: Location of Well (State Base Plane Coordinates - NAD 27): 6.5#L-80 2698 2-3/8"1930' 6930 - 6994 50-029-23055-01-00 Intermediate Conductor/Structural Single Zone Service - Disp NoYesPost initial injection MIT req'd: NoYes 5 Diverter Sketch Comm. TVD API Number: MD Sr Pet Geo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Stratigraphic Test Development - Gas Service - Supply Coalbed Gas Shale Gas 2.Operator Name:5.Bond Blanket 5 Single Well 3. 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 6. Proposed Depth: 7. Property Designation (Lease Number): 8. DNR Approval Number:13.Approximate spud date: 9.Acres in Property: 14. 9250 Distance to Nearest Property: Location of Well (Governmental Section): 4b. 2560 780 18.Specifications Top - Setting Depth - Bottom Casing Weight Grade TVDHole Coupling Length TVD (including stage data) 3-1/4"8840' 6558'73 sx Class 'G' (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):Effect. Depth MD (ft): Effect. Depth TVD (ft):Junk (measured): Casing Length Size MD 20" 29 - 109 7-5/8" 28 - 2726 28 - 2653 7418 5-1/2" x 3-1/2"217 sx Class 'G'26 - 7444 26 - 7090 Liner Perforation Depth MD (ft):Perforation Depth TVD (ft): 20. Attachments Property Plat BOP Sketch5 Drilling Program 5 Time v. Depth Plot Permit to Drill Number: Permit Approval Date: Reentry Hydraulic Fracture planned? Sr Pet Eng Sr Res Eng Cement Volume Comm. Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Hyd511 11.18.2021 By Samantha Carlisle at 3:13 pm, Nov 18, 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: 2021.11.18 14:17:22 -09'00' Monty M Myers BOPE test to 3500 psi. Variance to 20 AAC 25.112(i) approved for alternate plug placement. DLB 11/22/2021 X DSR-11/18/21 X X X 221-101 X X X 298329 MGR26NOV21 DLB dts 11/30/2021 11/30/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.30 11:28:05 -09'00' To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 18, 2021 Re: PBU L-106A Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well PBU L-106 with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for L-106A Producer: See L-106 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will set a 3-1/2" whipstock. A 2.80" window + 10’ of formation out of the 3-1/2” casing. The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 2-3/8” L-80 solid liner and cemented in place. The well will be selectively perforated post rig (see future L-106A Perf Sundry). This completion will completely isolate and abandon the parent Kuparuk perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference L-106 Sundry submitted in concert with this request for full details. x General work scope of Pre-Rig work: 1. Slickline: Dummy WS drift 2. Fullbore: MIT-IA and MIT-T Rig Work - (Estimated to start in February 2022): 1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,983 psi a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d. Open well and ensure zero pressure 2. Set 3-1/2” whipstock a. Set whipstock at 6,938’ MD b. Orient whipstock to 160 LOHS 3. Mill 2.80” single string window (out of 3-1/2”) plus 10’ of rathole. a. Top of window (whipstock pinch point) at 6,938’ MD. b. Mill window with straight motor c. Hold 11.8 ppg MPD while milling window 4. Drill – Build & Lateral a. 2-3/8” BHA with GR/RES / Bi-center Bit (3.25”) b. 42° DLS build section – 614’ MD / Planned TD 7,552’ MD c. 12° DLS lateral section – 1,288’ MD / Planned TD 8,840’ MD d. Drill with a constant bottom hole pressure for entire sidetrack e. Pressure deployment will be utilized f. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run g. No flow test prior to laying down drilling BHA Sundry 321-595 PTD 221-101 5. Run and Cement 2-3/8” L-80 solid liner a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Release from liner and come out of hole. c. Make up cementing BHA and sting into liner shoe. Swap the well over to 2% KCl. d. Cement liner with 15 bbls, 15.3 ppg Class G (TOC to TOL).* e. Freeze protect well from ~2200’ MD (min) f. RDMO Post Rig: 1. V: Valve & tree work 2. S: Set LTP* (if necessary) 3. C: Post rig perforate ~400’ (see future L-106A Perf Sundry) 4. S: Set live LGLVs 5. T: Portable test separator flowback * Approved alternate plug placement per 20 AAC 25.112(i) Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow 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 and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (6,938’ MD - 6,584’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,040 psi 4,040 psi 11.8 B Annular friction - ECD (psi/ft)624 psi 0 psi 0.09 C Mud Hydrostatic (ppg)2,944 psi 2,944 psi 8.6 B+C Mud + ECD Combined 3,569 psi 2,944 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 471 psi 1,096 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The maximum reservoir pressure is expected to be 3,633 psi at 6,500’ TVD (10.7 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,983 psi. DLB 11/22/2021 pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. gg Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom holegp g q py p pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surfacepyg ppgg p DLB 11/22/21 Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain constant BHP. x KWF will be stored on location. The tankage will contain 1.5 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 Completion: A minimum MW 10.8 ppg KWF to be used for liner deployment. Will target 11.8 ppg to match managed pressure target. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 3.25” hole for the entirety of the production hole section. Liner Program: x 2-3/8”, 6.5#, L-80 solid/cemented liner: 6,910’ MD – 8,840’ MD (1,930’ liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 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 2-3/8” safety joint including a TIW valve for all tubulars ran in hole. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. Directional: x Directional plan attached. Maximum planned hole angle is 114°. Inclination at kick off point is 1.26°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 9,250’ x Distance to nearest well within pool – 780’ 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 ~400’ perforated post rig – See future L-106A Perf sundry Anti-Collision Failures: x No failures Hazards: x PBU L-pad is an H2S pad. The highest recorded H2S well on the pad was from L-110 (1,110 ppm) in 2021. Last recorded H2S on L-116 was 120 ppm in 2021 x Two fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 6WDQGDUG3URSRVDO5HSRUW 1RYHPEHU 3ODQ/$ZSD +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ / 3ODQ/ 3ODQ/$ 5850 6000 6150 6300 6450 6600 6750 6900 7050 7200 7350 7500True Vertical Depth (300 usft/in)1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 Vertical Section at 89.47° (300 usft/in) L-106A wp07 tgt01 L-106A wp07 tgt02 L-106A wp07 tgt03 L-106A wp07 tgt04 L-106A wp07 tgt05 L-106A wp07 Polygon 6 5 0 0 700 0 7455 L-106 2-1/8" x 3 3/4" 7 0 0 0 7500800085008840L-106A wp07a Start Dir 9º/100' : 6938' MD, 6583.57'TVD : 160° LT TF Start Dir 42º/100' : 6958' MD, 6603.56'TVD Start Dir 12º/100' : 7551.72' MD, 6614.82'TVD Fault Crossing Fault Crossing Total Depth : 8839.51' MD, 6557.96' TVD Hilcorp North Slope, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: L-106 Ground Level: 50.40 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 5978143.05 583357.44 70° 21' 0.9017 N 149° 19' 23.6308 W SURVEY PROGRAM Date: 2021-11-11T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 109.65 6938.00 L-106 Srvy #1 MWD+IFR+MS (L-106) 3_MWD (BP MWD+IFR+MS-WOCA) 6938.00 8839.51 L-106A wp07a (Plan: L-106A) 3_MWD REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: L-106, True North Vertical (TVD) Reference:DF @ 79.22usft (L-106) Measured Depth Reference:DF @ 79.22usft (L-106) Calculation Method:Minimum Curvature Project:Prudhoe Bay Site:L Well:Plan: L-106 Wellbore:Plan: L-106A Design:L-106A wp07a CASING DETAILS TVD TVDSS MD Size Name 6557.97 6478.75 8839.51 2-1/8 2-1/8" x 3 3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 6938.00 1.26 73.27 6583.57 124.41 1755.95 0.00 0.00 1757.03 Start Dir 9º/100' : 6938' MD, 6583.57'TVD : 160° LT TF 2 6958.00 0.75 308.30 6603.56 124.56 1756.06 9.00 -160.00 1757.14 Start Dir 42º/100' : 6958' MD, 6603.56'TVD 3 6998.00 16.10 149.19 6643.06 119.92 1758.71 42.00 -160.00 1759.75 4 7174.22 90.11 149.19 6741.66 7.13 1825.98 42.00 0.00 1825.97 5 7226.72 110.00 139.47 6732.52 -34.68 1855.83 42.00 -25.00 1855.43 6 7376.72 110.10 71.88 6675.20 -69.97 1981.49 42.00 -77.00 1980.76 7 7476.72 110.05 27.02 6639.25 -10.85 2050.58 42.00 -82.00 2050.39 8 7551.72 107.00 60.14 6614.82 39.67 2098.91 42.00 90.00 2099.19 Start Dir 12º/100' : 7551.72' MD, 6614.82'TVD 9 7701.72 89.00 60.14 6594.04 113.32 2227.20 12.00 180.00 2228.16 10 7801.72 89.02 72.14 6595.78 153.69 2318.47 12.00 90.00 2319.80 11 8001.72 101.88 92.54 6576.63 180.41 2514.27 12.00 57.00 2515.84 12 8126.72 107.81 106.80 6544.47 160.38 2633.02 12.00 65.00 2634.39 13 8251.72 98.86 94.41 6515.55 138.30 2752.24 12.00 -125.00 2753.40 14 8379.51 84.94 100.86 6511.32 121.36 2878.43 12.00 155.00 2879.44 15 8454.51 84.69 91.82 6518.11 113.12 2952.59 12.00 -92.00 2953.51 16 8639.51 84.14 114.12 6536.35 72.07 3130.87 12.00 92.50 3131.40 17 8839.51 83.63 89.99 6557.96 30.83 3323.87 12.00 -92.50 3324.01 Total Depth : 8839.51' MD, 6557.96' TVD -750-625-500-375-250-12501252503755006257508751000South(-)/North(+) (250 usft/in)1500 1625 1750 1875 2000 2125 2250 2375 2500 2625 2750 2875 3000 3125 3250 3375 3500 3625 3750 3875West(-)/East(+) (250 usft/in)L-106A Fault2L-106A Fault1L-106A E/W FaultL-106A wp07 PolygonL-106A wp07 tgt05L-106A wp07 tgt04L-106A wp07 tgt03L-106A wp07 tgt02L-106A wp07 tgt0152505500575062506 7 5 07100L-1062-1/8" x 3 3/4"655 8L-106A wp07aStart Dir 9º/100' : 6938' MD, 6583.57'TVD : 160° LT TFStart Dir 42º/100' : 6958' MD, 6603.56'TVDStart Dir 12º/100' : 7551.72' MD, 6614.82'TVDFault CrossingFault CrossingTotal Depth : 8839.51' MD, 6557.96' TVDCASING DETAILSTVDTVDSS MDSize Name6557.97 6478.75 8839.51 2-1/8 2-1/8" x 3 3/4"Project: Prudhoe BaySite: LWell: Plan: L-106Wellbore: Plan: L-106APlan: L-106A wp07aWELL DETAILS: Plan: L-106Ground Level: 50.40+N/-S +E/-W Northing Easting Latitude 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N149° 19' 23.6308 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: L-106, True NorthVertical (TVD) Reference: DF @ 79.22usft (L-106)Measured Depth Reference:DF @ 79.22usft (L-106)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-11-11T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool109.65 6938.00 L-106 Srvy #1 MWD+IFR+MS (L-106) 3_MWD (BP MWD+IFR+MS-WOCA)6938.00 8839.51 L-106A wp07a (Plan: L-106A) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)7000 7125 7250 7375 7500 7625 7750 7875 8000 8125 8250 8375 8500 8625 8750 8875 9000 9125 9250 9375Measured Depth (250 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference6938.00 To 8840.42Project: Prudhoe BaySite: LWell: Plan: L-106Wellbore: Plan: L-106APlan: L-106A wp07aCASING DETAILSTVD TVDSS MD Size Name6557.97 6478.75 8839.51 2-1/8 2-1/8" x 3 3/4" Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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. 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