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Home My WebLink About172-015Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 InspectNo:susAGE231113104117 Well Pressures (psi): Date Inspected:11/5/2023 Inspector:Adam Earl If Verified, How?LAT / LONG Suspension Date:1/17/2023 #322-715 Tubing:34 IA:75 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Brian Woolley Date AOGCC Notified:11/2/2023 Type of Inspection:Initial Well Name:BELUGA RIV UNIT 212-24 Permit Number:1720150 Wellhead Condition Dry-Hole tree. Good working condition Surrounding Surface Condition First snow about an inch the morning of inspection. Was still able to see. Area looked ok. Condition of Cellar No water, clear of trash and debris. Comments Verified Lat/Long by plat map Supervisor Comments Inspection results acceptable despite snow on ground Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, January 12, 2024         1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Hilcorp Alaska, LLC Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,380 feet 2,983 feet true vertical 6,380 feet N/A feet Effective Depth measured 2,983 feet feet true vertical 2,983 feet feet Perforation depth Measured depth See schematic feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Casey Morse, Well Integrity Engineer Contact Email:casey.morse@hilcorp.com Authorized Title: Noel Nocas, Operations Manager 907-564-5278 Contact Phone: 907-777-8322 365' 365' Burst Collapse 520 psi 1,950 psi 3,810 psi 1,530 psi 3,450 psi 6,330 psi measured TVD Production Liner 3,202' 6,376' Casing Structural 3,202' 6,376' 3,202' 6,376' Plugs Junk measured Length 79' 365' 79'Conductor Surface Intermediate 30" 20" 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 021128 Beluga River / Sterling - Beluga Gas STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 172-015 50-283-20037-00-00 Size 79' 0 750 0 N/A0 N/A 13-3/8" 9-5/8" 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 3. Address: Beluga River Unit (BRU) 212-24 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 75 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:26 am, Nov 22, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.21 09:59:06 - 09'00' Noel Nocas (4361) Suspended Well Inspection Data Well: Beluga River Unit 212-24 Surface Location: 2000' FNL, 50' FWL, Sec 24, T13N, R10W, SM, AK Permit to Drill: 172-015 API: 50-283-20037-00-00 AOGCC Inspection Date: 11/6/23 AOGCC Inspector: Adam Earl Size Pressure (psi) Tubing NA NA Casing 9-5/8 75 OA 13-3/8 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: Condition of Wellhead: Dry hole tree. Valves good working order Condition of Surrounding Surface Location: Good, no trash or dunnage noticed. Follow Up Actions needed: No Currently the well is plugged just above the Sterling A sand and pressure tested. This well is currently being evaluated as a future sidetrack candidate. Attachments: Current Well Schematic Picture(s) Plat - 1/4mile radius of wellbore Picture Well Sign Picture IA Pressure Gauge Picture OA Pressure Gauge Picture IA Pressure Gauge on Swab Valve Wellhead Looking North Wellhead Looking East Wellhead Looking South Wellhead Looking West Plat Quarter-mile Buffer 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,380'N/A Casing Collapse Structural Conductor Surface 520psi Intermediate 1,950psi Production 3,810psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,330psi6,376'6,376' 79' 365' 3,202' Perforation Depth MD (ft): 6,376'9-5/8" 13-3/8"3,202' 30" 20" 79' 365' 3,450psi 1,530psi 79' 365' 3,202' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 3,379'2,983'2,983'0psi 2,983' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 021128 172-015 50-283-20037-00-00 Beluga River Sterling-Beluga Gas Same CO 802 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 212-24 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 6.5# / N-80 4,414' December 29, 2022 See Schematic See Schematic See Schematic See Schematic 2-7/8" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 m n P s t : 66 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 322-715 By Anne Prysunka at 3:44 pm, Dec 21, 2022 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2022.12.21 15:06:59 -09'00' Noel Nocas (4361) Wellsite inspection within 12 months of approval. Provide AOGCC opportunity to accompany the inspection. Variance to approved to suspend well with only 10' of cement above perfs. Final abandonment will require additional 15' of cement per 20 AAC 25.112(c)(1)(E) 10-407 after suspension work is completed. DLB 12/27/2022 X BJM 1/7/23 DSR-1/9/23 10-404 to include report of wellsite inspection per 20 AAC 25.110(f) Brett W. Huber, Sr. GCW 01/17/23 JLC 1/17/2023 1/17/23 RBDMS JSB 011923 Well Prognosis Well Name: BRU 212-24 API Number: 50-283-20037-00-00 Current Status: SI Gas Well Permit to Drill Number: 172-015 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Maximum BHP: 1308 psi (3022’ TVD) Based on 0.43 psi/ft gradient MPSP: 0 psi Plugged and fluid packed wellbore Well Status Plugged back gas producer Brief Well Summary Exhausted gas well that was decompleted, plugged back in the 9-5/8 production casing, and prepped for a rig sidetrack in the summer of 2022. A CBL was run over across the sidetrack interval of the 9-5/8” casing showing poor to no cement at this depth. To place remedial cement at this depth, the casing was punched and perforated to establish a circulation path from the 9-5/8” casing to the 9-5/8” x 13-3/8” annulus; all attempts were unsuccessful and a flow path could not be established. A second CBL was logged under pressure and showed multiple drilling mud beds that are believed to be blocking the flow path to this annulus. Additionally, while pressuring up on the annulus, a slow bleed off was observed that did not communicate to the casing. Currently the well is plugged just above the Sterling A sand and pressure tested. The objective of this sundry is to suspend the well while it is further evaluated as a sidetrack candidate. Notes Regarding Wellbore Condition 10/30/22 35’ (110 gal) of cement dumped on top of CIBP at 3022’, TOC at 2986’. 11/12/22 TOC tagged w/ slickline, 1600 psi MIT passed dropping 22 psi in 30 minutes Procedure 1. Review COAs in Approved Sundry 10-403 Form 2. RU E-Line, dump bail 35’ of cement on CIBP at 3022’ (completed 10/30/22) 3. Perform AOGCC witnessed tag and MIT to 1600 psi (completed 11/12/22) Attachments: 1) Current Schematic 2) Current Wellhead Diagram _____________________________________________________________________________________ Updated by DMA 11-17-22 SCHEMATIC Beluga River Unit Well: BRU 212-24 Last Completed: 11/17/1984 PTD: 172-015 API: 50-283-20037-00-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30''Conductor 120#Weld 32''79' 20''Surface 94#H-40 Butt 19.124''365' 13-3/8"Intermediate 68#K-55 Butt 12.415''3,202' 9-5/8"Prod Casing 43.5#P-110 Butt 8.755''1,478' 9-5/8"Prod Casing 43.5#N-80 8RD 8.755''3,282' 9-5/8"Prod Casing 43.5#S-95 Butt 8.755''6,376' TUBING DETAILS 2-7/8"Prod. Long String 6.5#N-80 8RD 2.441''4,414’ 30” 9-5/8” RKB to MSL = 98’ RKB to GL = 20.7’ PBTD = 2,983’ MD / 2,983’ TVD TD = 6,380’ MD / 3,379’ TVD Max Angle = < 1 deg Min I.D. Short string: 2.25” Long string: 2.205” 20” 13-3/8” 6 7 8 9 10 11 12 13 A P1 P2 P3 P4 P5 4 5 H, I F, G B-D C D 1 2 3 4A 4B Long String ID.Depth MD (ft.)ID (in.)Description 1 2994-2997 2997-3017’ Tbg punch, no communication (7/04/22) Perf w 2-7/8” gun, no comm (8/15/22) 2 3,022 9-5/8” CIBP (set 7/3/22, Passed 3000psi MIT) w/ 35' cement - TOC @ 2,983' 10/30/22 3 3,045 Jet cut (6/27/22) 4 3,051 3 Otis RDH Dual Packer 4A 3,100 Magna Range Plug 4B 3200-02 Tubing punches (6/22/19) 5 3,300 CIBP 06/22/19 6 3,854 2.5 Brown 57k Shear Safety Joint 7 3,887 2.313 Otis 'XA' Closed Sliding Sleeve 8 3,923 3 Otis 40k Shear RH Packer 9 4,302 2.5 Brown 57k Shear Safety Joint 10 4,337 2.313 Otix 'XA' Closed Sliding Sleeve (Closed 9/94) 11 4,373 2.375 Otis 40k Shear RH Packer 12 4,411 2.205 Otis 'XN' Nipple (Pulled plug 9/94) 13 4,414 2.36 Otis Shear Sub & TIW Re-entry Guide Short String ID.Depth MD (ft.)ID (in.)Description C 3,088 2.205 Otis 'XN' Nipple D 3,092 2.36 Otis Shear Out Sub Plugs/Fish ID.Depth MD (ft.)ID Date Description P1 3,412 -9/1/1994 Class G Cement Plug P2 3,624 -9/1/1994 20/40 Sand Plug P3 3,752 -9/1/1994 Fill P4 4,621 --Collapsed 9-5/8" Csg worked w/ swage & csg. Roller P5 4,957 Plug set in 1984 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status A 3,255'3,343'3,255'3,343'4 10/21/1984 Sqz A 3,362'3,436'3,362'3,436'50 4 10/23/1984 Isolated B 3,469'3,582'3,469'3,582'4 9/29/1973 Sqz C 3,624'3,752'3,624'3,752'61 4 10/23/1984 Isolated D 3,755'3,894'3,755'3,894'59 4 9/28/1973 Isolated D 3,939'4,002'3,939'4,002'4 9/28/1973 Isolated E 4,049'4,328'4,049'4,328'80 4 9/28/1973 Isolated F 4,392'4,778'4,392'4,778'50 4 10/14/1984 Isolated G 4,808'4,927'4,808'4,927'36 4 9/19/1973 Fill G 5,032'5,126'5,032'5,126'4 9/28/1984 Sqz H 5,162'5,714'5,162'5,714'4 9/26/1973 Sqz I 5,766'5,919'5,766'5,919'4 9/26/1973 Sqz I 5,999'6,022'5,999'6,022'4 9/16/1973 Plug Superseded Beluga River 212-24 Current 05/09/2019 13 3/8'’ 9 5/8'’ 2 7/8'’ Casing head, CIW-WF, 13 5/8 3M x 13 3/8 SOW, w/ 2- 2 1/16 5M EFO Tubing head, FMC-TC, 13 5/8 3M x 11 3M, w/ 2- 2 1/16 5M SSO, BG bottom prep Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Tree cap, 2 9/16 3M Triple segmented x 2 7/8 EUE 8rd lift Beluga River Unit BRU 212-24 13 3/8 x 9 5/8 x 2 7/8 x 2 7/8 x 2 3/8 Tubing hanger, Triple, FMC- TC-3C, 11 x 2 7/8 EUE 8rd lift and susp, w/ 2 1/2'’ type IS BPV profiles, AA trim 2 7/8'’ Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Swabs, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 2 3/8'’ Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Swabs, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Heater String Superseded This is no longer on the well. wrong wellhead diagram- bjm 1 Carlisle, Samantha J (OGC) From:McLellan, Bryan J (OGC) Sent:Tuesday, January 17, 2023 7:26 AM To:McLellan, Bryan J (OGC) Subject:FW: [EXTERNAL] BRU 212-24 (PTD 172-015) Suspension Sundry Attachments:BRU 212-24 Schematic 01-09-22.pdf Correctingthewellnameonthesubjectlineofthebelowemailchain.Thereisnota“T”attheendofthewellname. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission 333W7thAve Anchorage,AK99501 Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:JacobFlora<Jake.Flora@hilcorp.com> Sent:Monday,January9,202310:45AM To:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov> Subject:RE:[EXTERNAL]BRU212Ͳ24T(PTD172Ͳ015)SuspensionSundry Bryan, Hilcorprequestsavariancetoleavethewellwithlessthan25’ofcementovertheperforationsonthebasisthatit passedaStatewitnessedpressureteston11/12/2022. Pleasefindattachedanupdatedwellborediagramreflectingtherequestedinformationandcorrections. Letmeknowifyouneedanythingadditional, Thanks, Jake From:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov> Sent:Monday,January9,202310:24AM To:JacobFlora<Jake.Flora@hilcorp.com> Subject:RE:[EXTERNAL]BRU212Ͳ24T(PTD172Ͳ015)SuspensionSundry Jake, Youcanrequestavariancetoleavethewellwithonly10’abovetheperfsuntilthefinalP&Asinceitpassedapressure test. Pleasemakeafewupdatestothediagramsothatit’sclearforwhoeverplansthefutureP&A. 1. ShowTOCdepthinside9Ͳ5/8”casing. CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 2 2. Indicatewhatyouthinkthegreysubstanceinthe9Ͳ5/8”x13Ͳ3/8”annulusisandthesourceofthatinformation (CBL,orcalculated)andestimatedtop. 3. CorrecttheTVDatTDofthewell.Ithinkit’sincorrect. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission 333W7thAve Anchorage,AK99501 Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:JacobFlora<Jake.Flora@hilcorp.com> Sent:Friday,January6,20239:47AM To:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov> Cc:Roby,DavidS(OGC)<dave.roby@alaska.gov>;Boyer,DavidL(OGC)<david.boyer2@alaska.gov> Subject:RE:[EXTERNAL]BRU212Ͳ24T(PTD172Ͳ015)SuspensionSundry HelloBryan, 1. Myapologies,thesubmittedwellheaddiagramisincorrect.Attachedisthecurrentwellheaddiagram. 2. The9Ͳ5/8CIBPwassetat3022’andthetubingpunches,perforating,anddumpbailerrunswerecorrelatedby taggingthisplug.Basedonthis,thebelownumbersarewhatshouldbeused: 3022’CIBP07/03/22(MITto3000psipassed7/3/22) 3017Ͳ20’tubingpunches07/04/22unabletocirc 2094Ͳ97’tubingpunches07/04/22unabletocirc 2997Ͳ3017’2Ͳ7/8perfgun08/15/22unabletocirc 35galofcementdumpedonCIBPat3022’.WitnessedMITto1600psipassedon11/12/22. TOC=2987’ =7’overthehighesttubingpunchat2994’ =10’overthehighestperforationat2997’ LetmeknowifyouneedmoredatainyourreviewͲ Thanks, Jake From:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov> Sent:Thursday,January5,20237:09PM 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. 3 To:JacobFlora<Jake.Flora@hilcorp.com> Cc:Roby,DavidS(OGC)<dave.roby@alaska.gov>;Boyer,DavidL(OGC)<david.boyer2@alaska.gov> Subject:[EXTERNAL]BRU212Ͳ24T(PTD172Ͳ015)SuspensionSundry Jake, Acouplequestionsabouttheapplicationforsuspension: 1. Isthewellheadandtreediagramincludedwiththesundryaccurate?Doesitreallystillhaveadualtreeonthe well? 2. Howmanyfeetofcementisontopoftheperfs? 3. Notethatyou’llneedtoplanawellsiteinspectionwithin12monthsofapprovalofthissundry. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission 333W7thAve Anchorage,AK99501 Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 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. 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CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. _____________________________________________________________________________________ Updated by DMA 11-17-22 SCHEMATIC Beluga River Unit Well: BRU 212-24 Last Completed: 11/17/1984 PTD: 172-015 API: 50-283-20037-00-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30''Conductor 120#Weld 32''79' 20''Surface 94#H-40 Butt 19.124''365' 13-3/8"Intermediate 68#K-55 Butt 12.415''3,202' 9-5/8"Prod Casing 43.5#P-110 Butt 8.755''1,478' 9-5/8"Prod Casing 43.5#N-80 8RD 8.755''3,282' 9-5/8"Prod Casing 43.5#S-95 Butt 8.755''6,376' TUBING DETAILS 2-7/8"Prod. Long String 6.5#N-80 8RD 2.441''4,414’ 30” 9-5/8” RKB to MSL = 98’ RKB to GL = 20.7’ PBTD =2,983’ MD /2,983’TVD TD = 6,380’ MD / 6,380’ TVD Max Angle = <1 deg Min I.D. Short string: 2.25” Long string: 2.205” 20” 13-3/8” 6 7 8 9 10 11 12 13 A P1 P2 P3 P4 P5 4 5 H, I F, G B-D C D 1 2 3 4A 4B Pressurized CBL on 8/15/22 shows multiple mud beds from 1600-2950’ TOC @ 2987’ (10’ over perf holes) (7’ over punch holes Long String ID. Depth MD (ft.) ID (in.) Description 1 2994-2997 2997-3017’ Tbg punch, no communication (7/04/22) Perf w 2-7/8” gun, no comm (8/15/22) 2 3,022 9-5/8” CIBP set 7/3/22 (3000psi MIT),35' cement dumped 10/30/22, TOC @ 2987’ (1600psi MIT) 3 3,045 Jet cut (6/27/22) 4 3,051 3 Otis RDH Dual Packer 4A 3,100 Magna Range Plug 4B 3200-02 Tubing punches (6/22/19) 5 3,300 CIBP 06/22/19 6 3,854 2.5 Brown 57k Shear Safety Joint 7 3,887 2.313 Otis 'XA' Closed Sliding Sleeve 8 3,923 3 Otis 40k Shear RH Packer 9 4,302 2.5 Brown 57k Shear Safety Joint 10 4,337 2.313 Otix 'XA' Closed Sliding Sleeve (Closed 9/94) 11 4,373 2.375 Otis 40k Shear RH Packer 12 4,411 2.205 Otis 'XN' Nipple (Pulled plug 9/94) 13 4,414 2.36 Otis Shear Sub & TIW Re-entry Guide Short String ID. Depth MD (ft.) ID (in.) Description C 3,088 2.205 Otis 'XN' Nipple D 3,092 2.36 Otis Shear Out Sub Plugs/Fish ID. Depth MD (ft.) ID Date Description P1 3,412 -9/1/1994 Class G Cement Plug P2 3,624 -9/1/1994 20/40 Sand Plug P3 3,752 -9/1/1994 Fill P4 4,621 --Collapsed 9-5/8" Csg worked w/ swage &csg. Roller P5 4,957 Plug set in 1984 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,255'3,343'3,255'3,343'4 10/21/1984 Sqz A 3,362'3,436'3,362'3,436'50 4 10/23/1984 Isolated B 3,469'3,582'3,469'3,582'4 9/29/1973 Sqz C 3,624'3,752'3,624'3,752'61 4 10/23/1984 Isolated D 3,755'3,894'3,755'3,894'59 4 9/28/1973 Isolated D 3,939'4,002'3,939'4,002'4 9/28/1973 Isolated E 4,049'4,328'4,049'4,328'80 4 9/28/1973 Isolated F 4,392'4,778'4,392'4,778'50 4 10/14/1984 Isolated G 4,808'4,927'4,808'4,927'36 4 9/19/1973 Fill G 5,032'5,126'5,032'5,126'4 9/28/1984 Sqz H 5,162'5,714'5,162'5,714'4 9/26/1973 Sqz I 5,766'5,919'5,766'5,919'4 9/26/1973 Sqz I 5,999'6,022'5,999'6,022'4 9/16/1973 Plug Beluga River 212-24 Temp abandonment 05/11/2022 13 3/8'’ 9 5/8'’ Casing head, CIW-WF, 13 5/8 3M x 13 3/8 SOW, w/ 2- 2 1/16 5M EFO Tubing head, FMC-TC, 13 5/8 3M x 11 3M, w/ 2- 2 1/16 5M SSO, BG bottom prep Beluga River Unit BRU 212-24 13 3/8 x 9 5/8 By Anne Prysunka at 9:41 am, Nov 18, 2022 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221115 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 233-23 50283201360100 222050 10/8/2022 Halliburton RCBL BRU 212-24 50283200370000 172015 8/15/2022 AK E-Line CBL/PERF BRU 214-13 50283201870000 222117 10/23/2022 AK E-Line CBL Please include current contact information if different from above. T37258 T37259 T37260 BRU 212-24 50283200370000 172015 8/15/2022 AK E-Line CBL/PERF Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.15 15:32:43 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 24 Township: 13N Range: 10W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 6380 ft MD Lease No.: ADL 0021128 Operator Rep: Suspend: XXX P&A: Conductor: 30" O.D. Shoe@ 79 Feet Csg Cut@ Feet Surface: 20" O.D. Shoe@ 365 Feet Csg Cut@ Feet Intermediate: 13 3/8" O.D. Shoe@ 3202 Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 6376 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 2 7/8" O.D. Tail@ 3095 Feet Tbg Cut@ 3051 Feet Tubing: 2 7/8" O.D. Tail@ 4144 Feet Tbg Cut@ 3045 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 3022 ft 2997 ft 8.6 ppg Wireline tag Pre-Test PSI Initial 15 min 30 min 45 min Result 0 Tubing 1683 1670 1661 0 IA 1683 1670 1661 0 OA 110 110 110 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Suspension plug. Tag top of cement at 2997 ft MD (slick line measurement) with 175# tool string. Both SS and LS tubing are cutoff. November 12, 2022 Brian Bixby Plug Verification BRU 212-24 Hilcorp Alaska LLC PTD 1720150; Sundry 322-300 none Test Data: P Casing Removal: Michael Hibbert Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-1112_Plug_Verification_BRU_212-24_bb David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220928 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 07A 501332028401 214060 7/12/2022 AK E-Line CIBP GPT BCU 18RD 501332058401 222033 7/13/2022 AK E-Line Perf BCU 18RD 501332058401 222033 7/16/2022 AK E-Line GPT Perf BCU 18RD 501332058401 222033 7/23/2022 AK E-Line GPT CIBP Perf BRU 212-24 502832003700 172015 6/27/2022 AK E-Line CBL BRU 212-24 502832003700 172015 7/5/2022 AK E-Line CIBP CBL TBG END 1-45 500292199100 189124 7/23/2022 AK E-Line Perf END 4-02 500292178900 188022 7/21/2022 AK E-Line Perf HVB B-16 502312004000 212133 6/23/2022 AK E-Line Drift, Plug, Cement IRU 241-01 502832018400 221076 8/5/2022 AK E-Line CBL IRU 241-01 502832018400 221076 8/9/2022 AK E-Line Perf Kalotsa 6 501332068500 219114 7/16/2022 AK E-Line Perf KTU 24-06H 501332049000 199073 7/15/2022 AK E-Line GPT Perf MPU S-34 500292317100 203130 7/5/2022 AK E-Line Drift PBU F-26C 500292198703 213045 8/4/2022 AK E-Line Patch/LDL SRU 213-15 501332065200 215100 8/3/2022 AK E-Line GPT Perf Please include current contact information if different from above. T37068 T37069 T37069 T37069 T37070 T37070 T37071 T37072 T37073 T37081 T37081 T37074 T37075 T37076 T37077 T37078 BRU 212-24 502832003700 172015 6/27/2022 AK E-Line CBL BRU 212-24 502832003700 172015 7/5/2022 AK E-Line CIBP CBL TBG Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.30 12:44:16 -08'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:McLellan, Bryan J (OGC) To:Jacob Flora Subject:RE: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Update and Plan Date:Thursday, September 22, 2022 4:35:00 PM Jake, You can proceed with your plan below. You should plan to tag cement after it has had sufficient time to set up. Both tag and MIT should have 48 hrs notice for opportunity to witness. Minimum test pressure is 1500 psi. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Thursday, September 22, 2022 11:17 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Update and Plan Hi Bryan, The requested steps are not entirely different from the original sundry where we were setting a plug, dumping cement on it, getting a MIT, and then suspending it until it is sidetracked. It still is a possible sidetrack candidate in the future with additional work including solving the failed MIT on the annulus. For this year it was a more direct path to drill a grass roots well so we could stay on schedule and avoid stranding drilling equipment on that side of the Inlet like we did last year. Placing cement on the perfs is not urgent, but rather to leave the well in a pressure tested state while it is suspended and waiting on future plans. Let me know if you need more data or would like to talk through this one- Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, September 21, 2022 3:03 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Update and Plan Jake, Is this procedure something you can include in the suspension sundry application? Is placing cement across the perfs urgent? I think we need to discuss this a bit. Is this the result you were hoping for? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Tuesday, September 20, 2022 2:17 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: BRU 212-24 (PTD 172-015) Update and Plan Hello Bryan, I want to wrap up this well with a 10-404 and wanted to get you updated and ask for permission to dump cement over the open perfs and MIT the 9-5/8 ahead of placing the well in suspension. Quick recap of recent work: We pressured up the well and logged a CBL with 2000 psi on the casing. The CBL is attached and I believe shows several spots where there is mud or cement behind the 9-5/8 casing not allowing casing to annulus communication. We then shot a 20’ 2-7/8 gun just above the CIBP with 2000 psi on the casing and saw instant pressure fall off, but nothing on the annulus- I take this to prove we pushed the fluid into the formation. We tried for a few days to pressure up the 9-5/8 x 13-3/8 annulus without any luck. We put 1157 psi on the annulus and overnight it only fell to 1050 psi, while showing no communication with the casing. Hilcorp requests to take the following action: 1. Dump sufficient cement on the CIBP at 3022’ to cover the tubing punches and perforations from 2994’ – 3017’ 2. MIT the 9-5/8 casing to prove it still has integrity 3. Suspend the wellbore with a 10-403 Please advise if this is an acceptable path forward, Thanks, Jake Summary August 20-22 Pressured up took about 3 bbls of fluid. 0 to 2000# operator spent a lot of time bumping the pressure up every 100# of drop. Not much fluid used. IA 170. Pressured up to 2k 4:30 PM let set over night 6 AM 1225 IA 320. 4:00 pm 1157 IA 310 pressure up 2k. 6 am 1050 IA 300. 4:00 am 1000 IA 280. 6:30 am 900 IA 260. 6 am 800 IA 200. Total fluid injected thus far is 3.5 bbls From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, July 27, 2022 2:32 PM To: Jacob Flora <Jake.Flora@hilcorp.com>; Frank Roach <Frank.Roach@hilcorp.com> Subject: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Wellbore Abandonment Procedure Jake, Hilcorp has approval to reperforate the interval 2997-3017’ MD with larger guns, then attempt to establish communication between IA and OA by pressure testing the 9-5/8” casing to 3000 psi and pressure testing the 9- 5/8” x 13-3/8” annulus to 2000 psi. In both pressure test scenarios, if tests fail, attempt to establish circulation. We need to reconvene to discuss results and then agree on a plan forward before placing any cement. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Wednesday, July 27, 2022 2:11 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Frank Roach <Frank.Roach@hilcorp.com> Subject: RE: BRU 212-24 (PTD 172-015) Wellbore Abandonment Procedure Hi Bryan, I discussed with Frank and copied him on this email. Talking through it we believe the outer envelope is now the tested 9-5/8 casing, superseding the 13-3/8 casing as the surface casing. Once the window is drilled it will have to support a FIT test, which given the perforating and MIT data we just obtained, we are not worried about it failing up the annulus. The proposed perforating once more to abandon would further prove there is no annular communication at the window depth and obtain LOT data for well planning- both valuable. Thanks for your time working through this one, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, July 27, 2022 1:35 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: RE: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Wellbore Abandonment Procedure Jake, This leaking OA is potentially a problem for drilling the sidetrack. You can’t drill into new formation without competent surface casing. I think we should get Frank involved with this P&A planning. Maybe we should have a meeting. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Wednesday, July 27, 2022 1:17 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Wellbore Abandonment Procedure Bryan, Please see below ops summary for pumping down the OA. The 9-5/8 x 13-3/8 annulus “OA” will not pass a pressure test. It also took a much smaller amount of fluid to pressure up than would be expected. In Prudhoe where they’ve tracked a large amount of fluid packed 9-5/8 x 13-3/8 test data, they’ve seen more like 3-5 bbls to pressure up on this size of annulus. As noted in the below summaries the 9-5/8 casing “IA”, holds 3000 psi with a slow bleed. Let me know if you need more data, Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, July 27, 2022 11:08 AM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Wellbore Abandonment Procedure Jake, Have you done an MIT of the 9-5/8” x 13-3/8” annulus yet? If so, what were the results? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission th 333 W 7 Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Tuesday, July 19, 2022 2:18 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: BRU 212-24 (PTD 172-015) Wellbore Abandonment Procedure Hello Bryan, To comply with the requirement of placing cement inside and outside the 9-5/8 production casing and abandon the original wellbore Hilcorp proposes to do the following: 1. MIRU E-line, PT lubricator to 2000 psi 2. Pressure up the 9-5/8 casing to 1000 psi 3. Perforate ~2997-3017’ (20’ x 2-7/8 carrier loaded with large hole charges) 4. Monitor 9-5/8 x 13-3/8 annulus pressure for communication, POOH 5. Pressure 9-5/8 casing to 2500 psi trying to establish communication with annulus 6. If no communication is seen, dump bail 19 cubic feet of cement on CIBP at 3022’ a. 25’ of casing + annulus volume = 18.8 cf 7. If casing x annulus circulation is established, notify AOGCC to obtain approval for remedial cementing plan Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, July 18, 2022 6:13 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: RE: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) OK, give me a call. I recommend option 2, or some method of P&A’ing the existing wellbore before sidetracking to the new location. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Monday, July 18, 2022 2:56 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Hi Bryan, I’ll try you on the phone tomorrow to talk thru this one if that’s OK. The Ivan River 241-01 initial completion sundry is the only other outstanding item to hopefully wrap up soon. Thanks, Jake From: Jacob Flora Sent: Wednesday, July 13, 2022 2:07 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Hello Bryan, I went through this again with Todd. Regarding if the 9-5/8 was penetrated; he had the charges modeled prior to picking out the gun and is confident the 2” charges make it thru the 9-5/8 pipe. Another verification is the attached MIT after setting the 9-5/8 CIBP. It shows the 3000 psi MIT to be jug tight. Also attached is a picture of the charted circulation attempt showing a slow but steady bleed off. The contrast in these two are good evidence that we penetrated the 9-5/8 casing, and possibly the 13-3/8 casing. I still believe the drilling mud clay has settled out enough to be a barrier to circulating into this annulus. Regarding the 13-3/8 shoe at 3202’. They did a 1973 squeeze with 30 bbls cement behind pipe though holes at 3268-69’. Then in 1984 there was another 30 bbl squeeze at 3255-56’ (There are productive Sterling sands at the depth). From the records I see both were squeezes with breakdown pressures noted and not circulated in (i.e. no returns noted up the 9-5/8 x 13-3/8). This leads me to believe we don’t have an open shoe and that there is some degree of cement across it and isolating from the open hole below. I have two thoughts on the plug back requirement: 1. The future sidetrack window will be ~100’ uphole from the current CIBP. Given the close proximity to the top of the Sterling-Beluga Pool, the final abandonment plug could come at a later date after producing from the sidetrack. It would plug both wellbores at the top of the pool, and be located just above the liner top packer we would set in the sidetrack- usually we set these 200’ into the motherbore so in this case it would be around 2800’. 2. Should we need to do more now to provide a plug back barrier: We could shoot a 20’ perf gun with big hole charges (large diameter, shallow penetration), right above the 9-5/8 CIBP, and then dump bail a volume of cement on top equal to 25’ inside 13-3/8 casing. If the annulus is really open the cement would isolate across and behind the 9-5/8 casing, back into the 13-3/8. Below are snippets of the 1973 and 1984 CBLs in addition to the attachment: MIT, Circ Attempt, Charge Data Thanks for your time, I’m available should you want to meet up on this one- Jake 1973 CBL 1984 CBL From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, July 11, 2022 4:53 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Jake, The issue is that you don’t have a proper P&A plug in the well yet, with cement across all annuli and inside the casing. You should probably run a perf gun designed to perforate 9-5/8” casing. The gun definitely didn’t puncture the 13-3/8” casing because you would have frac’d away fluid when pressuring up to 3000 psi inside the 9-5/8” casing. Not sure if the 9-5/8’ casing was punctured or not, but there is no evidence of it. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Monday, July 11, 2022 3:15 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: BRU 212-24 (PTD 172-015) Bryan, While I was gone last week Todd had worked with you on a remedial cement job to place cement near the sidetrack depth after seeing little to no bond on the 9-5/8 CBL. A quick re-cap: 1. 2-7/8 long string & short string were pulled from the 9-5/8 casing 2. CIBP was set at 3022’ in 9-5/8 casing just above the long string tubing stub 3. CBL was logged, shows little to no cement in the 9-5/8 x 13-3/8 annulus 4. Casing was tested to 3000 psi and held (attached) 5. Tubing punched just above CIBP at 3017-20’ w 600 psi, saw no pressure drop 6. Pressured to 3500 psi, dropped 150 psi in 30 min 7. Repeated at 2994-97’, same results 8. Pressured OA to 2000 psi with 0.6 bbls, see no response in 9-5/8 casing 9. Perforate with 2” gun 2994-97’ w 1000 psi, no response on OA 10. Pressure to 3000 psi, dropped 88 psi in 30 minutes 11. NU dry hole tree, RDMO 401 Look at the CBL I believe there’s drilling mud beds from the original 9-5/8 cement job when the hole was full of mud, and that this mud has settled out over the years. Given this I don’t believe the 9-5/8 can be pulled with much certainty, however milling the dual casing window is something the drilling department is still comfortable with. Given that the 9-5/8 casing tested good and that we can’t remediate the annulus do you see any issues with allowing the dual casing sidetrack at ~2950’? The liner top packer would be set back inside the tested 9-5/8. I attached an updated schematic, the CBL, and 9-5/8 MIT for your review. This is not red hot on the schedule although we would like to keep pushing the planning ahead. Thanks for your time reviewing this request, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, July 5, 2022 9:27 AM To: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Cc: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] RE: BRU 212-24 (PTD 172-015) Remedial Cement Procedure Todd, As discussed on the phone, please make the following changes to the plan below: Step 7.e) Must leave at least 75’ of cement on top of the retainer inside the 9-5/8” casing per 20 AAC 25.112(c) (1)(E) for the P&A plug. The proposal to leave 1 bbl on top of the plug will only provide 13’ of cement, so you should plan to leave about 6 bbls on top of the plug to get 75’. Step 11) Tag the top of cement with E-line to verify TOC inside the 9-5/8” casing. Thanks Bryan Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Sunday, July 3, 2022 7:49 PM To: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Jacob Flora <Jake.Flora@hilcorp.com> Subject: RE: BRU 212-24 (PTD 172-015) Remedial Cement Procedure Todd, Hilcorp is approved to proceed with remedial cementing. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 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. 907-793-1231 Office 907-297-8474 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. Bryan, Victoria, Jacob From: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent: Sunday, July 3, 2022 4:27 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Jacob Flora <Jake.Flora@hilcorp.com>; edhooter295@gmail.com Subject: BRU 212-24 (PTD 172-015) Remedial Cement Procedure Hello Victoria / Mel / Bryan, Attached please find the CBL ran on BRU 212-24 in order to find TOC in the 9-5/8” x 13-3/8” annulus. Rig 401 is working this well over for a pre-rig sidetrack. There is no cement present in the anulus and we would like to move forward with a remedial cement job per sundry instructions. We set a CIBP at 3022’ and performed a successful MIT-T to 3000 psi. We propose the following plan: 1. MIRU eline and punch 9-5/8” casing from 3017’-3020’. Monitor OA for pressure response. 2. Rig up to take returns from OA and establish injectivity into holes at 3 bpm with lease water, do not exceed 2500 psi treating pressure. 3. RIH with eline and set 9-5/8” cement retainer at 3010’. 4. TIH with 2-7/8” work string and cement stinger assembly. Stab into and test retainer per service company recommendation. 5. MIRU cementers. 6. Establish injectivity by pumping 50 bbls lease water down work string taking returns from OA, do not exceed 2500 psi treating pressure. 7. If we are able to take returns pump the following schedule: a. 5 bbl freshwater spacer b. 90 bbls 14-15.8 ppg cement (TOC will be at ~500’) c. 5 bbl freshwater spacer d. Work string displacement volume lease water e. With 1 bbl remaining in work string un-sting from retainer and slowly POOH 50’ to let cement fall out on top of retainer. 8. If we are unable to get returns from the IA we will perform a squeeze with hesitation if necessary: a. 5 bbl freshwater spacer b. 30 bbls 14-15.8 ppg cement c. 5 bbl freshwater spacer d. Work string displacement volume lease water e. Target a squeeze pressure of 2000 psi for 30 minutes f. If unable to build squeeze pressure after 20 bbls injected, hesitate for 15 minutes and displace 5 more bbls cement. Repeat this process a second time with final 5 bbls cement. g. If unable to get a squeeze we will most likely attempt another 30 bbl hesitation squeeze. 9. Un-sting from retainer and POOH reversing out and remaining cement in string. 10. WOC 11. MIRU eline and perform CBL to find TOC. 12. MIT-T to 3000 psi, notify AOGSS 48 hours ahead of time for opportunity to witness. Please let me know if you have any questions or need additional data. Thanks and Happy 4th, Todd Todd Sidoti | Hilcorp Alaska | 907-632-4113 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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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. 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. 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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. 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 ifthe 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. 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. 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 onwardtransmission, 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. Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes AOGCC Eset # BRU 212-24 50283200370000 172015 7/27/2022 AK E-Line CIBP BRU 233-27 50283100260000 163002 7/2/2022 AK E-Line PERF HVA B-16 50231200400000 212133 6/23/2022 AK E-Line PLUG/CEMENT KBU 11-08Z 50133206290000 214044 6/22/2022 AK E-Line PERF KBU 33-06X 50133205290000 203183 6/18/2022 AK E-Line PLUG/CEMENT/PUNCH MPU I-17 50029232120000 204098 7/9/2022 Read CALIPER SRU 32A-33 50133101640100 191014 6/20/2022 Halliburton TMD3D-WFL + Report Please include current contact information if different from above. T36794 T36795 T36796 T36797 T36798 T36799 T36800 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.19 09:04:04 -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:AOGCC Records (CED sponsored) Subject:20220703 0749 APPROVAL to _ BRU 212-24 (PTD 172-015) Remedial Cement Procedure Date:Tuesday, July 5, 2022 8:24:45 AM From: Rixse, Melvin G (OGC) Sent: Sunday, July 3, 2022 7:49 PM To: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Jacob Flora <Jake.Flora@hilcorp.com> Subject: RE: BRU 212-24 (PTD 172-015) Remedial Cement Procedure Todd, Hilcorp is approved to proceed with remedial cementing. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 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. Bryan, Victoria, Jacob From: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent: Sunday, July 3, 2022 4:27 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Jacob Flora <Jake.Flora@hilcorp.com>; edhooter295@gmail.com Subject: BRU 212-24 (PTD 172-015) Remedial Cement Procedure Hello Victoria / Mel / Bryan, Attached please find the CBL ran on BRU 212-24 in order to find TOC in the 9-5/8” x 13-3/8” annulus. Rig 401 is working this well over for a pre-rig sidetrack. There is no cement present in the anulus and we would like to move forward with a remedial cement job per sundry instructions. We set a CIBP at 3022’ and performed a successful MIT-T to 3000 psi. We propose the following plan: 1. MIRU eline and punch 9-5/8” casing from 3017’-3020’. Monitor OA for pressure response. 2. Rig up to take returns from OA and establish injectivity into holes at 3 bpm with lease water, do not exceed 2500 psi treating pressure. 3. RIH with eline and set 9-5/8” cement retainer at 3010’. 4. TIH with 2-7/8” work string and cement stinger assembly. Stab into and test retainer per service company recommendation. 5. MIRU cementers. 6. Establish injectivity by pumping 50 bbls lease water down work string taking returns from OA, do not exceed 2500 psi treating pressure. 7. If we are able to take returns pump the following schedule: a. 5 bbl freshwater spacer b. 90 bbls 14-15.8 ppg cement (TOC will be at ~500’) c. 5 bbl freshwater spacer d. Work string displacement volume lease water e. With 1 bbl remaining in work string un-sting from retainer and slowly POOH 50’ to let cement fall out on top of retainer. 8. If we are unable to get returns from the IA we will perform a squeeze with hesitation if necessary: a. 5 bbl freshwater spacer b. 30 bbls 14-15.8 ppg cement c. 5 bbl freshwater spacer d. Work string displacement volume lease water e. Target a squeeze pressure of 2000 psi for 30 minutes f. If unable to build squeeze pressure after 20 bbls injected, hesitate for 15 minutes and displace 5 more bbls cement. Repeat this process a second time with final 5 bbls cement. g. If unable to get a squeeze we will most likely attempt another 30 bbl hesitation squeeze. 9. Un-sting from retainer and POOH reversing out and remaining cement in string. 10. WOC 11. MIRU eline and perform CBL to find TOC. 12. MIT-T to 3000 psi, notify AOGSS 48 hours ahead of time for opportunity to witness. Please let me know if you have any questions or need additional data. Thanks and Happy 4th, Todd Todd Sidoti | Hilcorp Alaska | 907-632-4113 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________BELUGA RIV UNIT 212-24 JBR 07/22/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 2-3/8", 2-7/8" & 2-7/8" dual joints used. Ram door leak-replace seal for a pass. TIW leak-bleed down & function for a pass. Annular 21 secs; Rams 8 secs; HCR 2 secs. Test Results TEST DATA Rig Rep:Chris HannevoldOperator:Hilcorp Alaska, LLC Operator Rep:Ed Hooter Contractor/Rig No.:Hilcorp 401 PTD#:1720150 DATE:6/30/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM220701110844 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 1146 Sundry No: 322-300 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.NA Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 FP Inside BOP 2 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8 P #1 Rams 1 2-7/8 Duals P #2 Rams 1 2-3/8x3-1/2 P #3 Rams 1 Blinds P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 4-1/16 P HCR Valves 1 4-1/16 P Kill Line Valves 3 2-1/16&4-1/16 P Check Valve 0 NA BOP Misc 1 Door FP System Pressure P3000 Pressure After Closure P1750 200 PSI Attained P28 Full Pressure Attained P118 Blind Switch Covers:PAll stations Nitgn. Bottles (avg):P6@2250 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 9 9 9 9 9 FP FP Ram door leak-TIW leak- Annular 21 secs; Rams 8 secs; HCR 2 secs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ϭϯͲϯͬϴ͟ ϱ ϲ ϳ ϴ ϵ ϭϬ ϭϭ ϭϮ ϭϯ WϮ Wϯ Wϰ Wϱ Wϲ ϰ dƵďŝŶŐWƵŶĐŚĞƐ Λϯ͕ϮϬϬ͛Ͳϯ͕ϮϬϮ͛ ϬϲͬϮϮͬϭϵ ϰ ,͕/ &͕' Ͳ ϭ ϯ Ϯ , ϭϯϯͬϴǆϵͲϱͬϴdK ϯϮϲϮ͛;ϭϬͬϮϬͬϴϰ>Ϳ ΎΎϯϮďďůĐŵƚƐƋǌĂƚ ϯϮϱϱ͛ĂĨƚĞƌ>͕dK ŶŽƚƌĞͲůŽŐŐĞĚΎΎ Wϭ >ŽŶŐ^ƚƌŝŶŐ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϭ ϭϰϳ Ϯ͘ϯϭϯ KƚŝǆΖyΖEŝƉƉůĞ Ϯ Ϯ͕ϵϴϰ Ϯ͘ϯϭ ƌŽǁŶΖΖ^ĂĨĞƚǇ:ŽŝŶƚ ϯ ϯ͕Ϭϭϲ Ϯ͘ϯϭϯ KƚŝǆΖyΖůŽƐĞĚ^ůŝĚŝŶŐ^ůĞĞǀĞ ϰ ϯ͕Ϭϱϭ ϯ KƚŝƐZ,ƵĂůWĂĐŬĞƌ ϰ ϯ͕ϯϬϬ /WϬϲͬϮϮͬϭϵ ϱ ϯ͕ϯϰϯ Ϯ͘ϱ ϭϯůĂƐƚ:ŽŝŶƚƐ͗ϲ;ϯϯϰϯͲϯϰϲϰͿΘϳ;ϯϲϮϭͲϯϳϲϬͿ ϲ ϯ͕ϴϱϰ Ϯ͘ϱ ƌŽǁŶϱϳŬ^ŚĞĂƌ^ĂĨĞƚǇ:ŽŝŶƚ ϳ ϯ͕ϴϴϳ Ϯ͘ϯϭϯ KƚŝƐΖyΖůŽƐĞĚ^ůŝĚŝŶŐ^ůĞĞǀĞ ϴ ϯ͕ϵϮϯ ϯ KƚŝƐϰϬŬ^ŚĞĂƌZ,WĂĐŬĞƌ ϵ ϰ͕ϯϬϮ Ϯ͘ϱ ƌŽǁŶϱϳŬ^ŚĞĂƌ^ĂĨĞƚǇ:ŽŝŶƚ ϭϬ ϰ͕ϯϯϳ Ϯ͘ϯϭϯ KƚŝǆΖyΖůŽƐĞĚ^ůŝĚŝŶŐ^ůĞĞǀĞ;ůŽƐĞĚϵͬϵϰͿ ϭϭ ϰ͕ϯϳϯ Ϯ͘ϯϳϱ KƚŝƐϰϬŬ^ŚĞĂƌZ,WĂĐŬĞƌ ϭϮ ϰ͕ϰϭϭ Ϯ͘ϮϬϱ KƚŝƐΖyEΖEŝƉƉůĞ;WƵůůĞĚƉůƵŐϵͬϵϰͿ ϭϯ ϰ͕ϰϭϰ Ϯ͘ϯϲ KƚŝƐ^ŚĞĂƌ^ƵďΘd/tZĞͲĞŶƚƌǇ'ƵŝĚĞ ^ŚŽƌƚ^ƚƌŝŶŐ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϭϯϵ͛ Ϯ͘ϯϭϯ KƚŝǆΖyΖEŝƉƉůĞ ϯϬϱϭ͛ KƚŝƐŽůůĞƚ>ĂƚĐŚ;ϯ͘ϴϱ͛K>Ϳ ϯ͕Ϭϴϴ Ϯ͘ϮϬϱ KƚŝƐΖyEΖEŝƉƉůĞ ϯ͕ϬϵϮ Ϯ͘ϯϲ KƚŝƐ^ŚĞĂƌKƵƚ^Ƶď ,ĞĂƚĞƌ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ , ϰϯ Ϯ͘ϯϳϱ ƌŽƐƐŽǀĞƌϮ͘ϴϳϱΗǆϮ͘ϯϳϱΗ , ϭϰϲ͛ KƚŝƐyͲEŝƉƉůĞ , ϭ͕ϱϴϰ͛ DƵůĞƐŚŽĞ WůƵŐƐͬ&ŝƐŚ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ / ĂƚĞ ĞƐĐƌŝƉƚŝŽŶ Wϭ ΕϮ͕ϴϭϬ͛ ϬϲͬϬϴͬϬϵ dŽŽů^ƚƌŝŶŐϭͲϭͬϮ͟Εϯϭ͛ǁŝƚŚĂϱ͛ϭͲϭͬϮ͟ĐƵƚƚĞƌďĂƌ WϮ ϯ͕ϰϭϮ Ͳ ϵͬϭͬϭϵϵϰ ůĂƐƐ'ĞŵĞŶƚWůƵŐ Wϯ ϯ͕ϲϮϰ Ͳ ϵͬϭͬϭϵϵϰ ϮϬͬϰϬ^ĂŶĚWůƵŐ Wϰ ϯ͕ϳϱϮ Ͳ ϵͬϭͬϭϵϵϰ &ŝůů Wϱ ϰ͕ϲϮϭ Ͳ Ͳ ŽůůĂƉƐĞĚϵͲϱͬϴΗƐŐǁŽƌŬĞĚǁͬƐǁĂŐĞΘĐƐŐ͘ZŽůůĞƌ Wϲ ϰ͕ϵϱϳ WůƵŐƐĞƚŝŶϭϵϴϰ WZ&KZd/KE d/> ^ĂŶĚƐͬŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ ^W& ĂƚĞ ^ƚĂƚƵƐ ϯ͕ϮϱϱΖ ϯ͕ϯϰϯΖ ϯ͕ϮϱϱΖ ϯ͕ϯϰϯΖ ϰ ϭϬͬϮϭͬϭϵϴϰ ^Ƌǌ ϯ͕ϯϲϮΖ ϯ͕ϰϯϲΖ ϯ͕ϯϲϮΖ ϯ͕ϰϯϲΖ ϱϬ ϰ ϭϬͬϮϯͬϭϵϴϰ ŽƉĞŶ ϯ͕ϰϲϵΖ ϯ͕ϱϴϮΖ ϯ͕ϰϲϵΖ ϯ͕ϱϴϮΖ ϰ ϵͬϮϵͬϭϵϳϯ ^Ƌǌ ϯ͕ϲϮϰΖ ϯ͕ϳϱϮΖ ϯ͕ϲϮϰΖ ϯ͕ϳϱϮΖ ϲϭ ϰ ϭϬͬϮϯͬϭϵϴϰ /ƐŽůĂƚĞĚ ϯ͕ϳϱϱΖ ϯ͕ϴϵϰΖ ϯ͕ϳϱϱΖ ϯ͕ϴϵϰΖ ϱϵ ϰ ϵͬϮϴͬϭϵϳϯ /ƐŽůĂƚĞĚ ϯ͕ϵϯϵΖ ϰ͕ϬϬϮΖ ϯ͕ϵϯϵΖ ϰ͕ϬϬϮΖ ϰ ϵͬϮϴͬϭϵϳϯ /ƐŽůĂƚĞĚ ϰ͕ϬϰϵΖ ϰ͕ϯϮϴΖ ϰ͕ϬϰϵΖ ϰ͕ϯϮϴΖ ϴϬ ϰ ϵͬϮϴͬϭϵϳϯ /ƐŽůĂƚĞĚ & ϰ͕ϯϵϮΖ ϰ͕ϳϳϴΖ ϰ͕ϯϵϮΖ ϰ͕ϳϳϴΖ ϱϬ ϰ ϭϬͬϭϰͬϭϵϴϰ /ƐŽůĂƚĞĚ ' ϰ͕ϴϬϴΖ ϰ͕ϵϮϳΖ ϰ͕ϴϬϴΖ ϰ͕ϵϮϳΖ ϯϲ ϰ ϵͬϭϵͬϭϵϳϯ &ŝůů ' ϱ͕ϬϯϮΖ ϱ͕ϭϮϲΖ ϱ͕ϬϯϮΖ ϱ͕ϭϮϲΖ ϰ ϵͬϮϴͬϭϵϴϰ ^Ƌǌ , ϱ͕ϭϲϮΖ ϱ͕ϳϭϰΖ ϱ͕ϭϲϮΖ ϱ͕ϳϭϰΖ ϰ ϵͬϮϲͬϭϵϳϯ ^Ƌǌ / ϱ͕ϳϲϲΖ ϱ͕ϵϭϵΖ ϱ͕ϳϲϲΖ ϱ͕ϵϭϵΖ ϰ ϵͬϮϲͬϭϵϳϯ ^Ƌǌ / ϱ͕ϵϵϵΖ ϲ͕ϬϮϮΖ ϱ͕ϵϵϵΖ ϲ͕ϬϮϮΖ ϰ ϵͬϭϲͬϭϵϳϯ WůƵŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ:>>ϬϱͬϭϬͬϮϮ WZKWK^ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϭϮͲϮϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϳͬϭϵϴϰ Wd͗ϭϳϮͲϬϭϱ W/͗ϱϬͲϮϴϯͲϮϬϬϯϳͲϬϬ ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ / ƚŵ ϯϬΖΖ ŽŶĚƵĐƚŽƌ ϭϮϬη tĞůĚ ϯϮΖΖ ϳϵΖ ϮϬΖΖ ^ƵƌĨĂĐĞ ϵϰη ,ͲϰϬ Ƶƚƚ ϭϵ͘ϭϮϰΖΖ ϯϲϱΖ ϭϯͲϯͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ ϲϴη <Ͳϱϱ Ƶƚƚ ϭϮ͘ϰϭϱΖΖ ϯ͕ϮϬϮΖ ϵͲϱͬϴΗ WƌŽĚĂƐŝŶŐ ϰϯ͘ϱη WͲϭϭϬ Ƶƚƚ ϴ͘ϳϱϱΖΖ ϭ͕ϰϳϴΖ ϵͲϱͬϴΗ WƌŽĚĂƐŝŶŐ ϰϯ͘ϱη EͲϴϬ ϴZ ϴ͘ϳϱϱΖΖ ϯ͕ϮϴϮΖ ϵͲϱͬϴΗ WƌŽĚĂƐŝŶŐ ϰϯ͘ϱη ^Ͳϵϱ Ƶƚƚ ϴ͘ϳϱϱΖΖ ϲ͕ϯϳϲΖ ϮͲϯͬϴΗ ,ĞĂƚĞƌ^ƚƌŝŶŐ ϰ͘ϳη EͲϴϬ ϴZ Ϯ͘ϰϰϭΖΖ ϭ͕ϱϴϰΖ dh/E'd/>^ ϮͲϳͬϴΗ WƌŽĚ͘>ŽŶŐ^ƚƌŝŶŐ ϲ͘ϱη EͲϴϬ ϴZ Ϯ͘ϰϰϭΖΖ цϯ͕Ϭϰϱ͛ ϯϬ͟ ϵͲϱͬϴ͟ Z<ƚŽD^>сϵϴ͛Z<ƚŽ'>сϮϬ͘ϳ͛ dDсϲ͕ϯϴϬ͛dsсϯ͕ϯϳϵ͛ WDсϰ͕ϵϱϳ͛Wdsсϰ͕ϵϱϴ͛ DĂǆŶŐůĞсфϭĚĞŐ DŝŶ/͘͘ ,ĞĂƚĞƌƐƚƌŝŶŐ͗Ϯ͘ϯϳϱ͟ ^ŚŽƌƚƐƚƌŝŶŐ͗Ϯ͘Ϯϱ͟ >ŽŶŐƐƚƌŝŶŐ͗Ϯ͘ϮϬϱ͟ϮϬ͟ ϭϯͲϯͬϴ͟ ϱ ϲ ϳ ϴ ϵ ϭϬ ϭϭ ϭϮ ϭϯ Wϭ WϮ Wϯ Wϰ Wϱ ϰ dƵďŝŶŐWƵŶĐŚĞƐ Λϯ͕ϮϬϬ͛Ͳϯ͕ϮϬϮ͛ ϬϲͬϮϮͬϭϵ ϰ ,͕/ &͕' Ͳ ϭϯϯͬϴǆϵͲϱͬϴdK ϯϮϲϮ͛;ϭϬͬϮϬͬϴϰ>Ϳ ΎΎϯϮďďůĐŵƚƐƋǌĂƚ ϯϮϱϱ͛ĂĨƚĞƌ>͕dK ŶŽƚƌĞͲůŽŐŐĞĚΎΎ /WǁϮϱ͛Đŵƚ ΛΕϯϬϬϬ >ŽŶŐ^ƚƌŝŶŐ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ цϯ͕ϬϬϬ͛ /WǁͬϮϱ͛ĐĞŵĞŶƚ ϰ ϯ͕Ϭϱϭ ϯ KƚŝƐZ,ƵĂůWĂĐŬĞƌ цϯ͕ϭϬϬ͛ /WǁͬϮϱ͛ĐĞŵĞŶƚ ϰ ϯ͕ϯϬϬ /WϬϲͬϮϮͬϭϵ ϱ ϯ͕ϯϰϯ Ϯ͘ϱ ϭϯůĂƐƚ:ŽŝŶƚƐ͗ϲ;ϯϯϰϯͲϯϰϲϰͿΘϳ;ϯϲϮϭͲϯϳϲϬͿ ϲ ϯ͕ϴϱϰ Ϯ͘ϱ ƌŽǁŶϱϳŬ^ŚĞĂƌ^ĂĨĞƚǇ:ŽŝŶƚ ϳ ϯ͕ϴϴϳ Ϯ͘ϯϭϯ KƚŝƐΖyΖůŽƐĞĚ^ůŝĚŝŶŐ^ůĞĞǀĞ ϴ ϯ͕ϵϮϯ ϯ KƚŝƐϰϬŬ^ŚĞĂƌZ,WĂĐŬĞƌ ϵ ϰ͕ϯϬϮ Ϯ͘ϱ ƌŽǁŶϱϳŬ^ŚĞĂƌ^ĂĨĞƚǇ:ŽŝŶƚ ϭϬ ϰ͕ϯϯϳ Ϯ͘ϯϭϯ KƚŝǆΖyΖůŽƐĞĚ^ůŝĚŝŶŐ^ůĞĞǀĞ;ůŽƐĞĚϵͬϵϰͿ ϭϭ ϰ͕ϯϳϯ Ϯ͘ϯϳϱ KƚŝƐϰϬŬ^ŚĞĂƌZ,WĂĐŬĞƌ ϭϮ ϰ͕ϰϭϭ Ϯ͘ϮϬϱ KƚŝƐΖyEΖEŝƉƉůĞ;WƵůůĞĚƉůƵŐϵͬϵϰͿ ϭϯ ϰ͕ϰϭϰ Ϯ͘ϯϲ KƚŝƐ^ŚĞĂƌ^ƵďΘd/tZĞͲĞŶƚƌǇ'ƵŝĚĞ ^ŚŽƌƚ ^ƚƌŝŶŐ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϯ͕Ϭϴϴ Ϯ͘ϮϬϱ KƚŝƐΖyEΖEŝƉƉůĞ ϯ͕ϬϵϮ Ϯ͘ϯϲ KƚŝƐ^ŚĞĂƌKƵƚ^Ƶď WůƵŐƐͬ&ŝƐŚ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ / ĂƚĞ ĞƐĐƌŝƉƚŝŽŶ Wϭ ϯ͕ϰϭϮ Ͳ ϵͬϭͬϭϵϵϰ ůĂƐƐ'ĞŵĞŶƚWůƵŐ WϮ ϯ͕ϲϮϰ Ͳ ϵͬϭͬϭϵϵϰ ϮϬͬϰϬ^ĂŶĚWůƵŐ Wϯ ϯ͕ϳϱϮ Ͳ ϵͬϭͬϭϵϵϰ &ŝůů Wϰ ϰ͕ϲϮϭ Ͳ Ͳ ŽůůĂƉƐĞĚϵͲϱͬϴΗƐŐǁŽƌŬĞĚǁͬƐǁĂŐĞΘĐƐŐ͘ZŽůůĞƌ Wϱ ϰ͕ϵϱϳ WůƵŐƐĞƚŝŶϭϵϴϰ WZ&KZd/KEd/> ^ĂŶĚƐͬŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ ^W& ĂƚĞ ^ƚĂƚƵƐ ϯ͕ϮϱϱΖ ϯ͕ϯϰϯΖ ϯ͕ϮϱϱΖ ϯ͕ϯϰϯΖ ϰ ϭϬͬϮϭͬϭϵϴϰ ^Ƌǌ ϯ͕ϯϲϮΖ ϯ͕ϰϯϲΖ ϯ͕ϯϲϮΖ ϯ͕ϰϯϲΖ ϱϬ ϰ ϭϬͬϮϯͬϭϵϴϰ /ƐŽůĂƚĞĚ ϯ͕ϰϲϵΖ ϯ͕ϱϴϮΖ ϯ͕ϰϲϵΖ ϯ͕ϱϴϮΖ ϰ ϵͬϮϵͬϭϵϳϯ ^Ƌǌ ϯ͕ϲϮϰΖ ϯ͕ϳϱϮΖ ϯ͕ϲϮϰΖ ϯ͕ϳϱϮΖ ϲϭ ϰ ϭϬͬϮϯͬϭϵϴϰ /ƐŽůĂƚĞĚ ϯ͕ϳϱϱΖ ϯ͕ϴϵϰΖ ϯ͕ϳϱϱΖ ϯ͕ϴϵϰΖ ϱϵ ϰ ϵͬϮϴͬϭϵϳϯ /ƐŽůĂƚĞĚ ϯ͕ϵϯϵΖ ϰ͕ϬϬϮΖ ϯ͕ϵϯϵΖ ϰ͕ϬϬϮΖ ϰ ϵͬϮϴͬϭϵϳϯ /ƐŽůĂƚĞĚ ϰ͕ϬϰϵΖ ϰ͕ϯϮϴΖ ϰ͕ϬϰϵΖ ϰ͕ϯϮϴΖ ϴϬ ϰ ϵͬϮϴͬϭϵϳϯ /ƐŽůĂƚĞĚ & ϰ͕ϯϵϮΖ ϰ͕ϳϳϴΖ ϰ͕ϯϵϮΖ ϰ͕ϳϳϴΖ ϱϬ ϰ ϭϬͬϭϰͬϭϵϴϰ /ƐŽůĂƚĞĚ ' ϰ͕ϴϬϴΖ ϰ͕ϵϮϳΖ ϰ͕ϴϬϴΖ ϰ͕ϵϮϳΖ ϯϲ ϰ ϵͬϭϵͬϭϵϳϯ &ŝůů ' ϱ͕ϬϯϮΖ ϱ͕ϭϮϲΖ ϱ͕ϬϯϮΖ ϱ͕ϭϮϲΖ ϰ ϵͬϮϴͬϭϵϴϰ ^Ƌǌ , ϱ͕ϭϲϮΖ ϱ͕ϳϭϰΖ ϱ͕ϭϲϮΖ ϱ͕ϳϭϰΖ ϰ ϵͬϮϲͬϭϵϳϯ ^Ƌǌ / ϱ͕ϳϲϲΖ ϱ͕ϵϭϵΖ ϱ͕ϳϲϲΖ ϱ͕ϵϭϵΖ ϰ ϵͬϮϲͬϭϵϳϯ ^Ƌǌ / ϱ͕ϵϵϵΖ ϲ͕ϬϮϮΖ ϱ͕ϵϵϵΖ ϲ͕ϬϮϮΖ ϰ ϵͬϭϲͬϭϵϳϯ WůƵŐ %HOXJD5LYHU &XUUHQW ϭϯϯͬϴΖ͛ ϵϱͬϴΖ͛ ϮϳͬϴΖ͛ ĂƐŝŶŐŚĞĂĚ͕/tͲt&͕ ϭϯϱͬϴϯDǆϭϯϯͬϴ^Kt͕ǁͬ ϮͲϮϭͬϭϲϱD&K dƵďŝŶŐŚĞĂĚ͕&DͲd͕ ϭϯϱͬϴϯDǆϭϭϯD͕ ǁͬϮͲϮϭͬϭϲϱD^^K͕ 'ďŽƚƚŽŵƉƌĞƉ sĂůǀĞ͕DĂƐƚĞƌƐ͕KdͲϮϬ͕ ϮϵͬϭϲϯDƚƌŝƉůĞƐĞŐŵĞŶƚĞĚ &͕,tK͕dͲϮϭ dƌĞĞĐĂƉ͕ϮϵͬϭϲϯDdƌŝƉůĞ ƐĞŐŵĞŶƚĞĚǆϮϳͬϴhϴƌĚ ůŝĨƚ ĞůƵŐĂZŝǀĞƌhŶŝƚ ZhϮϭϮͲϮϰ ϭϯϯͬϴǆϵϱͬϴǆϮϳͬϴǆϮϳͬϴ ǆϮϯͬϴ dƵďŝŶŐŚĂŶŐĞƌ͕dƌŝƉůĞ͕&DͲ dͲϯ͕ϭϭǆϮϳͬϴhϴƌĚůŝĨƚ ĂŶĚƐƵƐƉ͕ǁͬϮϭͬϮΖ͛ ƚǇƉĞ/^ WsƉƌŽĨŝůĞƐ͕ƚƌŝŵ ϮϳͬϴΖ͛ sĂůǀĞ͕DĂƐƚĞƌƐ͕KdͲϮϬ͕ ϮϵͬϭϲϯDƚƌŝƉůĞƐĞŐŵĞŶƚĞĚ &͕,tK͕dͲϮϭ sĂůǀĞ͕^ǁĂďƐ͕KdͲϮϬ͕ ϮϵͬϭϲϯDƚƌŝƉůĞƐĞŐŵĞŶƚĞĚ &͕,tK͕dͲϮϭ ϮϯͬϴΖ͛ sĂůǀĞ͕DĂƐƚĞƌƐ͕KdͲϮϬ͕ ϮϵͬϭϲϯDƚƌŝƉůĞƐĞŐŵĞŶƚĞĚ &͕,tK͕dͲϮϭ sĂůǀĞ͕DĂƐƚĞƌƐ͕KdͲϮϬ͕ ϮϵͬϭϲϯDƚƌŝƉůĞƐĞŐŵĞŶƚĞĚ &͕,tK͕dͲϮϭ sĂůǀĞ͕^ǁĂďƐ͕KdͲϮϬ͕ ϮϵͬϭϲϯDƚƌŝƉůĞƐĞŐŵĞŶƚĞĚ &͕,tK͕dͲϮϭ ,ĞĂƚĞƌ^ƚƌŝŶŐ %HOXJD5LYHU 7HPSDEDQGRQPHQW ϭϯϯͬϴΖ͛ ϵϱͬϴΖ͛ ĂƐŝŶŐŚĞĂĚ͕/tͲt&͕ ϭϯϱͬϴϯDǆϭϯϯͬϴ^Kt͕ǁͬ ϮͲϮϭͬϭϲϱD&K dƵďŝŶŐŚĞĂĚ͕&DͲd͕ ϭϯϱͬϴϯDǆϭϭϯD͕ ǁͬϮͲϮϭͬϭϲϱD^^K͕ 'ďŽƚƚŽŵƉƌĞƉ ĞůƵŐĂZŝǀĞƌhŶŝƚ ZhϮϭϮͲϮϰ ϭϯϯͬϴǆϵϱͬϴ ^dE/E'KZZ h>^dZ/E' d,Z/>>Z,^d,Z/',d͕hd,KZ/dzEd,yWdd/KEdK ^,hd/Ed,t>>d,/^/^Zd/KE͕Ezd/D͘ /DD/d>z&dZ^,hd/Ed,Z/>>Zt/>>EKd/&zd,Z/>>^/d ^hWZs/^KZEd,dKK>Wh^,Z͘ d,Z/>>^/d^hWZs/^KZ;t^>Ϳ/^d,KE>zKEt/d,d, hd,KZ/dzdKZKWEd,t>>&dZ/d,^E^,hd/E͘ d,/^EKd//^dKZD/EWK^dWZK'Z'h>d/KE͘ KWĞƋƵŝƉŵĞŶƚĂůŝŐŶŵĞŶƚ͗ ͻKƵƚƐŝĚĞŬŝůůůŝŶĞǀĂůǀĞŝƐĐůŽƐĞĚ͘ ͻ,ZǀĂůǀĞŽŶĐŚŽŬĞůŝŶĞŝƐĐůŽƐĞĚ͘ ͻŚŽŬĞŵĂŶŝĨŽůĚŝƐůŝŶĞĚǁŝƚŚŵĂŶƵĂůǀĂůǀĞƵƉƐƚƌĞĂŵĐůŽƐĞĚ ͻŚŽŬĞŝƐĐůŽƐĞĚ͘ ͻϮĞĂĐŚŽƉĞŶǁŽƌŬƐƚƌŝŶŐƐĂĨĞƚǇǀĂůǀĞƐĂŶĚǁƌĞŶĐŚĞƐĂƌĞĂǀĂŝůĂďůĞŽŶĨůŽŽƌ͘ ^ŚƵƚͲŝŶWƌŽĐĞĚƵƌĞ͗ ϭͿŚĞĐŬƚŚĞǁĞůůĨŽƌĨůŽǁ͕ŝĨŝƚŝƐĨůŽǁŝŶŐƐŚƵƚŝŶƚŚĞǁĞůů͘ ϮͿWŝĐŬƵƉƚŚĞůŽŶŐƐƚƌŝŶŐ&K^s͘ ϯͿ/ŶƐƚĂůůΘĐůŽƐĞǀĂůǀĞ͘ ϰͿWŝĐŬƵƉƚŚĞƐŚŽƌƚƐƚƌŝŶŐ&K^s ϱͿ/ŶƐƚĂůůĂŶĚĐůŽƐĞǀĂůǀĞ 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Jacob Flora To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] BRU 212-24 (PTD 172-015) RWO sundry questions Date:Tuesday, May 17, 2022 10:13:29 AM Attachments:BRU 212-24 well history (1984 RWO).pdf Hi Bryan, A few key updates: I found a note in the wellfile that said there was a PX set in the short string at 3006’ SLM (3088’ MD). Last week we pressure tested the short string and it held 2500 psi. We are working on a MITIA now. If we can’t get a pass my next step would be to set a CIBP in the long string (at ~3100) and try for a combo. Answers to your questions: 1. Why do you want to pull the tubing with the shallow plugs installed? You won’t be able to check for pressure or circulate. I’m planning to add a step to pull those plugs before pulling the tubing. Agree, we will pull them prior to pulling tubing. 2. Are you currently able to inject into the open perfs? If so, why not squeeze cement through a cement retainer per 20 AAC 25.112(c)(1)(D)? You need to request a variance to 20 AAC 25.112(C)(1)(E) otherwise, for setting the plug >50’ above the perfs. The short string has a plug in it and holds pressure. The long string may take injection, but I would prefer to keep the tubing clean to set a CIBP right at or below the packer, and know we had good isolation at the packer depth. In effort to sidetrack in good 9-5/8 x 13-3/8 cement, we want to cut and pull tubing deep as possible and I see the cement job as potentially compromising this. We request a variance 20 AAC 25.112(C)(1)(E) to accommodate plugging back 200’ above the perfs vs 50’ above the perfs. 3. What’s the planned depth of the whipstock? Planned WS depth is at ~2950’, just above the plug back depth (9-5/8 CIBP at ~3000’, with 25’ cmt cap, TOC at ~2975’) 4. Please send me details of the remedial cement job on the 9-5/8” casing. You will need to set the P&A plug across a zone of good cement outside the 9-5/8” and 13-3/8” casing. Plug depth will be pending result of CBL. Suggest setting the CIBP as deep as possible to maximize chance of finding good cement behind casing. Attached is the well history from the 1984 RWO where they did multiple squeezes, then ran a CBL, then did one more squeeze at 3255-56’ with 150 sx cement, drilled it out and did not re-log a CBL. The TOC is unknown, which is why we want a new CBL from the proposed 9-5/8 CIBP depth. We agree the goal should be to set the CIBP as deep as possible. I hope to cut the long string immediately above the packer, allowing a CIBP depth of ~3045’, which as you say will allow the best chance of good cement behind the 9-5/8 for milling the dual casing window. Please let me know if you need anything additional to evaluate, Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, May 16, 2022 3:13 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] BRU 212-24 (PTD 172-015) RWO sundry questions Jake, Thanks for including the part about the standing orders for pulling the dual completion in the sundry. A couple questions: 1. Why do you want to pull the tubing with the shallow plugs installed? You won’t be able to check for pressure or circulate. I’m planning to add a step to pull those plugs before pulling the tubing. 2. Are you currently able to inject into the open perfs? If so, why not squeeze cement through a cement retainer per 20 AAC 25.112(c)(1)(D)? You need to request a variance to 20 AAC 25.112(C)(1)(E) otherwise, for setting the plug >50’ above the perfs. 3. What’s the planned depth of the whipstock? 4. Please send me details of the remedial cement job on the 9-5/8” casing. You will need to set the P&A plug across a zone of good cement outside the 9-5/8” and 13-3/8” casing. Plug depth will be pending result of CBL. Suggest setting the CIBP as deep as possible to maximize chance of finding good cement behind casing. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,380'N/A Casing Collapse Structural Conductor Surface 520 psi Intermediate 1,950 psi Production 3,810 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: October 15, 2020 2-7/8" 6,376' Perforation Depth MD (ft): 3,202' See Attached Schematic 6,376' 6,376'9-5/8" 30" 20" 79' 13-3/8"3,202' 365'1,530 psi 79' 365' 3,202' 79' 365' 6.5# N-80 TVD Burst 3,095'; 4,414' 6,330 psi MD 3,450 psi Length Size N/A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0021128 172-015 50-283-20037-00-00 Beluga River Unit (BRU) 212-24 Beluga River / Undefined Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 6,380'4,957'4,957'~1134 4,957', 3,412', 3,300' Otis RDH Dual Packer, 2 Otis RH Packers; N/A 3,051' MD/TVD; 3,923' MD/TVD; 4,373' MD/TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:07 am, Oct 05, 2020 320-417 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.10.02 16:30:06 -08'00' Taylor Wellman DSR-10/12/2020gls 10-7-20 10-404 Perforate SFD 10/5/2020 SFD 10/5/2020 Spacing Exception Required? 20 AAC 25.055 - Statewide Spacing Comm. 10/21/2020 dts 10/21/2020 RBDMS HEW 11/3/2020 Well Prognosis Well: BRU 212-24 Date: 9/23/2020 Well Name: BRU 212-24 API Number: 50-283-20037-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 10/15/2020 Rig: Rigless Reg. Approval Req’d: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 172-015 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (907) 865-0665 (C) AFE Number Current Bottom Hole Pressure: ~650 psi @ 3,362’ TVD (Offset Well Survey 27JUL2012) Max. Expected BHP: ~1470 psi @ 3,362’ TVD (Virgin Pressure) Max. Potential Surface Pressure: ~1134 psi (Gas Gradient to Surface) Brief Well Summary: BRU 212-24 was originally completed as a triple string design with a diesel heater string. First production was 12/28/1978. This was a development well to prove up additional reserves on the North End. WO recompleted the well in 1984 with a dual string in order to locate and isolate water- isolating the Sterling B and the lower Beluga H,I. A coil tbg plug back in 1994 isolated Sterling C and Bel D - scope of work was to clean out sand in the long string and shut off water in the short string. A sand and cement plug was placed with coiled tbg in the SS. The well cum’d over 44 BCF of gas before being shut-in in 2005 from sand production. The SS was making over 5 MMCFD while the LS was struggling to stay online. A PX plug was set in the SS @ 124’ SS. A CIBP was set @ 3,300’ MD on 6/22/2019 followed immediately by a tbg punch in attempt to try and flow the open A sand intervals. The effort was not successful. Procedure Summary: The objective of this work is to perforate the Sterling A1, X3 and X2 sands in an attempt to return this well to production. Slickline Procedure: 1. MIRU slickline and pressure control equipment on short string. PT lubricator to 250 psi low / 2500 psi high. 2. RIH and pull 2-7/8” PX prong and then plug from X nipple located at 139’. 3. RIH with toolstring including drift for 2-1/8” guns and sample bailer. Drift to PBTD. If unable to drift to ~3350’ contact Operations Engineer. Decision to troubleshoot or rig up on long string and attempt to drift to PBTD will be made. 4. RDMO slickline. E-Line Procedure: 1. MIRU e-line and pressure control equipment to the short string. PT lubricator to 250 psi low / 2500 psi high. x Note that if we were unable to access PBTD through the short string, but able to through the long string, we will rig up on the long string and perforate through tubing. 2. Perforate the below sands with 2-1/8” 6 SPF 60 deg phased strip guns. (Short String) The objective of this work is to perforate the Sterling A1, X3 and X2 sands in an attempt to return this well to production. (Short String) Well Prognosis Well: BRU 212-24 Date: 9/23/2020 x Use GR/CCL to correlate to Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer (Todd Sidoti), Reservoir Engineer (Ben Siks), and Geologist (Trudi Hallett) for confirmation. x Monitor and record tubing, IA and OA pressures before and at 5, 10 and 15 minute intervals after shooting. x The first zone will be perforated with the well shut in. Once first zone is shot discuss strategy for subsequent zones with OE. 3. Turn well over to production. Proposed Perforated Intervals Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom ST_X2 ±3,070' ±3,085' 15' ±3,070' ±3,085' ST_X3 ±3,206' ±3,226' 20' ±3,206' ±3,226' ST_A1_ST ±3,275' ±3,285' 10' ±3,275' ±3,285' tubing, IA and OA pressures SFD 10/5/2020 (shoot thru tubing tail) Spacing exception required as perforations will open the well to the same pool as a well within the same governmental section and within 3000' of wells that are, or may be capable of, producing from the same pool. _____________________________________________________________________________________ Updated by DMA 07-05-19 SCHEMATIC Beluga River Unit Well: BRU 212-24 Last Completed: 11/17/1984 PTD: 172-015 API: 50-283-20037-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30'' Conductor 120# Weld 32'' 79' 20'' Surface 94# H-40 Butt 19.124'' 365' 13-3/8" Intermediate 68# K-55 Butt 12.415'' 3,202' 9-5/8" Prod Casing 43.5# P-110 Butt 8.755'' 1,478' 9-5/8" Prod Casing 43.5# N-80 8RD 8.755'' 3,282' 9-5/8" Prod Casing 43.5# S-95 Butt 8.755'' 6,376' 2-3/8" Heater String 4.7# N-80 8RD 2.441'' 1,584' TUBING DETAILS 2-7/8" Prod. Short String 6.5# N-80 Butt 2.441'' 3,095' 2-7/8" Prod. Long String 6.5# N-80 8RD 2.441'' 4,414' 30” 9-5/8” RKB to MSL = 98’ RKB to GL = 20.7’ TMD = 6,380’ TVD =3,379’ PBMD = 4,957’ PBTVD = 4,958’ Max Angle = < 1 deg Min I.D. Heater string: 2.375” Short string: 2.25” Long string: 2.205” 20” 13-3/8” 1 2 3 5 6 7 8 9 10 11 12 13 HA B C A A B C D D D E E F F F F G G H H I Sterling Sands A-C P1 P2 P3 P4 P5 Beluga Sands D-I A 4 Tubing Punches @ 3,200’-3,202’ 06/22/19 4A Long String ID. Depth MD (ft.) ID (in.) Description 1 147 2.313 Otix 'X' Nipple 2 2,984 2.31 Brown 'CC' Safety Joint 3 3,016 2.313 Otix 'XA' Closed Sliding Sleeve 4 3,051 3 Otis RDH Dual Packer 4A 3,300 CIBP 06/22/19 5 3,343 2.5 13 Blast Joints: 6 (3343-3464) & 7 (3621-3760) 6 3,854 2.5 Brown 57k Shear Safety Joint 7 3,887 2.313 Otis 'XA' Closed Sliding Sleeve 8 3,923 3 Otis 40k Shear RH Packer 9 4,302 2.5 Brown 57k Shear Safety Joint 10 4,337 2.313 Otix 'XA' Closed Sliding Sleeve (Closed 9/94) 11 4,373 2.375 Otis 40k Shear RH Packer 12 4,411 2.205 Otis 'XN' Nipple (Pulled plug 9/94) 13 4,414 2.36 Otis Shear Sub & TIW Re-entry Guide Short String ID. Depth MD (ft.) ID (in.) Description A 139 2.313 Otix 'X' Nipple w/ PX Plug B 3,088 2.205 Otis 'XN' Nipple C 3,092 2.36 Otis Shear Out Sub Heater ID. Depth MD (ft.) ID (in.) Description HA 43 2.375 Crossover 2.875"x2.375" Plugs/Fish ID. Depth MD (ft.) ID Date Description P1 3,412 - 9/1/1994 Class G Cement Plug P2 3,624 - 9/1/1994 20/40 Sand Plug P3 3,752 - 9/1/1994 Fill P4 4,621 - - Collapsed 9-5/8" Csg worked w/ swage & csg. Roller P5 4,957 Plug set in 1984 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,255' 3,343' 3,255' 3,343' 4 10/21/1984 Sqz A 3,362' 3,436' 3,362' 3,436' 50 4 10/23/1984 open B 3,469' 3,582' 3,469' 3,582' 4 9/29/1973 Sqz C 3,624' 3,752' 3,624' 3,752' 61 4 10/23/1984 Sand Plug D 3,755' 3,894' 3,755' 3,894' 59 4 9/28/1973 Fill D 3,939' 4,002' 3,939' 4,002' 4 9/28/1973 Sqz E 4,049' 4,328' 4,049' 4,328' 80 4 9/28/1973 Closed Sleeve F 4,392' 4,778' 4,392' 4,778' 50 4 10/14/1984 Open/partial fill G 4,808' 4,927' 4,808' 4,927' 36 4 9/19/1973 Fill G 5,032' 5,126' 5,032' 5,126' 4 9/28/1984 Sqz H 5,162' 5,714' 5,162' 5,714' 4 9/26/1973 Sqz I 5,766' 5,919' 5,766' 5,919' 4 9/26/1973 Sqz I 5,999' 6,022' 5,999' 6,022' 4 9/16/1973 Plug _____________________________________________________________________________________ Updated by TCS 09-28-20 PROPOSED SCHEMATIC Beluga River Unit Well: BRU 212-24 Last Completed: 11/17/1984 PTD: 172-015 API: 50-283-20037-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30'' Conductor 120# Weld 32'' 79' 20'' Surface 94# H-40 Butt 19.124'' 365' 13-3/8" Intermediate 68# K-55 Butt 12.415'' 3,202' 9-5/8" Prod Casing 43.5# P-110 Butt 8.755'' 1,478' 9-5/8" Prod Casing 43.5# N-80 8RD 8.755'' 3,282' 9-5/8" Prod Casing 43.5# S-95 Butt 8.755'' 6,376' 2-3/8" Heater String 4.7# N-80 8RD 2.441'' 1,584' TUBING DETAILS 2-7/8" Prod. Short String 6.5# N-80 Butt 2.441'' 3,095' 2-7/8" Prod. Long String 6.5# N-80 8RD 2.441'' 4,414' 30” 9-5/8” RKB to MSL = 98’ RKB to GL = 20.7’ TMD = 6,380’ TVD =3,379’ PBMD = 4,957’ PBTVD = 4,958’ Max Angle = < 1 deg Min I.D. Heater string: 2.375” Short string: 2.25” Long string: 2.205” 20” 13-3/8” 1 2 3 5 6 7 8 9 10 11 12 13 HA B C ST_X2 ST_X3 ST_A1_ST A B C D D D E E F F F F G G H H I Sterling Sands A-C P1 P2 P3 P4 P5 Beluga Sands D-I A 4 Tubing Punches @ 3,200’-3,202’ 06/22/19 4A Long String ID. Depth MD (ft.) ID (in.) Description 1 147 2.313 Otix 'X' Nipple 2 2,984 2.31 Brown 'CC' Safety Joint 3 3,016 2.313 Otix 'XA' Closed Sliding Sleeve 4 3,051 3 Otis RDH Dual Packer 4A 3,300 CIBP 06/22/19 5 3,343 2.5 13 Blast Joints: 6 (3343-3464) & 7 (3621-3760) 6 3,854 2.5 Brown 57k Shear Safety Joint 7 3,887 2.313 Otis 'XA' Closed Sliding Sleeve 8 3,923 3 Otis 40k Shear RH Packer 9 4,302 2.5 Brown 57k Shear Safety Joint 10 4,337 2.313 Otix 'XA' Closed Sliding Sleeve (Closed 9/94) 11 4,373 2.375 Otis 40k Shear RH Packer 12 4,411 2.205 Otis 'XN' Nipple (Pulled plug 9/94) 13 4,414 2.36 Otis Shear Sub & TIW Re-entry Guide Short String ID. Depth MD (ft.) ID (in.) Description A 139 2.313 Otix 'X' Nipple B 3,088 2.205 Otis 'XN' Nipple C 3,092 2.36 Otis Shear Out Sub Heater ID. Depth MD (ft.) ID (in.) Description HA 43 2.375 Crossover 2.875"x2.375" Plugs/Fish ID. Depth MD (ft.) ID Date Description P1 3,412 - 9/1/1994 Class G Cement Plug P2 3,624 - 9/1/1994 20/40 Sand Plug P3 3,752 - 9/1/1994 Fill P4 4,621 - - Collapsed 9-5/8" Csg worked w/ swage & csg. Roller P5 4,957 Plug set in 1984 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status ST_X2 ~3,070’ ~3,085’ ~3,070 ~3,085’ 6 - - ST_X3 ~3,206’ ~3,226’ ~3,206 ~3,226 6 - - ST_A1_ST ~3,275’ ~3,285’ ~3,275’ ~3,285 6 - - A 3,255' 3,343' 3,255' 3,343' 4 10/21/1984 Sqz A 3,362' 3,436' 3,362' 3,436' 50 4 10/23/1984 open B 3,469' 3,582' 3,469' 3,582' 4 9/29/1973 Sqz C 3,624' 3,752' 3,624' 3,752' 61 4 10/23/1984 Sand Plug D 3,755' 3,894' 3,755' 3,894' 59 4 9/28/1973 Fill D 3,939' 4,002' 3,939' 4,002' 4 9/28/1973 Sqz E 4,049' 4,328' 4,049' 4,328' 80 4 9/28/1973 Closed Sleeve F 4,392' 4,778' 4,392' 4,778' 50 4 10/14/1984 Open/partial fill G 4,808' 4,927' 4,808' 4,927' 36 4 9/19/1973 Fill G 5,032' 5,126' 5,032' 5,126' 4 9/28/1984 Sqz H 5,162' 5,714' 5,162' 5,714' 4 9/26/1973 Sqz I 5,766' 5,919' 5,766' 5,919' 4 9/26/1973 Sqz I 5,999' 6,022' 5,999' 6,022' 4 9/16/1973 Plug STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 "af 9L.x. JUL. 16 9C;49 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Ll Pull Tubing s`555� s u own Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ CI1a6g'% Approve rogmm ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing Punch❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 172-015 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-283-20037-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0021128 Beluga River Unit 212-24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beluga River/ Undefined Gas 11. Present Well Condition Summary: Total Depth measured 6,380 feet Plugs measured 3,300 & 4,957 feet true vertical 6,380 feet Junk measured N/A feet Effective Depth measured 4,957 feet Packer measured 3,928 & 4,373 feet true vertical 4,957 feet true vertical 3,928 & 4,373 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 30" 79' 79' Surface 365' 20" 365' 365' 1,530psi 520psi Intermediate 3,202' 13-3/8" 3,202' 3,202' 3,450psi 1,95opsi Production 6,376' 9-5/8" 6,376' 6,376' 6,330psi 3,81 Opal Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.5#/N-80 3p095 -MD 3,095'MD Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / N-80 4,4141MD 4,4141TVD Otis RDH Dual Pkr; 3,051' MD/TVD Packers and SSSV (type, measured and true vertical depth) 2 Otis RH Pkrs; N/A 3,923' MD/TVD 4,373' MD/TVD N/A; NIA 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 100 11 Subsequent to operation: 0 0 10 100 100 14. Attachments (required per 20 MC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Fal Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas j WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-242 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerr-hilcoro.com Authorized Signature. Date: \,7 Zo19 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 Submit Original Only s #418/ y '�B�Ms (JUL 1 e 1019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Stan Date End Date BRU 212-24 E-Line 50-283-20037-00-00 1 172-015 6/22/19 1 6/22/19 Daily Operations: 06/22/2019-Saturday Hold safety meeting. Permit to work. Mobilize to location. Spot in equipment and rig up. 0 psi WHP. Re-head Eline wire. Make up 2-7/8" CIBP. RIH Tag at 3,317'. 7.3' from CCL to top of plug. Correlate depth. Park CCL at 3,292.7'. Set CIBP at 3,300'. POOH to surface. Break down setting sleeve. Make up owen tubing punches. 18 shots. RIH CCL to top shot 4.2'. Correlate depth. PU and park CCL at 3,195.8'. Shoot punches from 3,200'-3,203.2'. Pressure slowly climbing from 0 psi. 40 psi at surface. Shut in well. Rig down E-line unit. Turn well over to production. Pressure has built to 160 psi over 3 hours. �I RKB to MSL =98' RKB to GL=20.7' Tubing Punches @ 3,200'-3,202' 06/22/19 TOC @ 3,290' S TIMID =6,380' TVD =3,379' PBMD=4,957' PBTVD=4,958' Max Angle = < 1 deg SCHEMATIC Min I.D. Heater string: 2.375" Short string: 2.25" Long string: 2.205" A Sterling Sands A -C A B C D Beluga Sands D-1 D Beluga River Unit Well: BRU 212-24 Last Completed: 11/17/1984 PTD: 172-015 API: 50-283-20037-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30" Conductor 120# 2.31 Weld 32" 79' 20" Surface 94# H-40 Butt 19.124" 365' 13-3/8" Intermediate 68# K-55 Butt 12.415" 3,202' 9-5/8" Prod Casing 43.5# P-110 Butt 8.755" 1,478' 9-5/8" Prod Casing 43.5# N-80 8RD 8.755" 3,282' 9-5/8" Prod Casing 43.5# S-95 Butt 8.755" 6,376' 2-3/8" Heater String 4.7# N-80 8RD 2.441" 1584' TUBING DETAILS 2-7/8" Prod. Short String 6.5# N-80 Butt 2.441" 3,095' 2-7/8" Prod. Long String 6.5# N-80 8RD 2.441" 4,414' Lone String ID. Depth MD (ft.) ID (in.) Description 1 147 2.313 Otix'X' Nipple 2 2,984 2.31 Brown'CC'Safety Joint 3 3,016 2.313 Otix'XA' Closed Sliding Sleeve 4 3,051 3 Otis RDH Dual Packer 4A 3,300 3,436' CIBP 06/22/19 5 . 3,343 2.5 13 Blast Joints: 6 (3343-3464) & 7 (3621-3760) 6 3,854 2.5 Brown 57k Shear Safety Joint 7 1 3,887 2.313 Otis'XA' Closed Sliding Sleeve 8 3,923 3 Otis 40k Shear RH Packer 9 4,302 2.5 Brown 57k Shear Safety Joint 10 4,337 2.313 Otix 'XA'Closed Sliding Sleeve (Closed 9/94) 11 4,373 2.375 Otis 40k Shear RH Packer 12 4,411 2.205 Otis'XN' Nipple (Pulled plug 9/94) 13 4,414 2.36 Otis Shear Sub &TIW Re-entry Guide Short String ID. Depth MD (ft.) ID (in.) Description A 124 N/A PX Plug Al 139 2.313 Otix'X' Nipple 8 3,088 2.205 Otis'XN' Nipple C 3,092 2.36 Otis Shear Out Sub Heater ID. Depth MD (ft.) ID (in.) I Description HA 43 2.375 1 Crossover 2.875"x2.375" Plues/Fish ID. Depth MD (ft.) ID Date Description Pi 3,412 - 9/1/1994 Class G Cement Plug P2 3,624 - 9/1/1994 20/40 Sand Plug P3 3,752 - 9/1/1994 Fill P4 4,621 - - Collapsed 9-5/8" Csg worked w/ swage & csg. Roller P5 4,957 3,436' Plug set in 1984 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,255' 3,343' 3,255' 3,343' 4 10/21/1984 Sqz A 3,362' 3,436' 3,362' 3,436' 50 4 10/23/1984 open B 3,469' 3,582' 3,469' 3,582' 4 9/29/1973 Sqz C 3,624' 3,752' 3,624' 3,752' 61 4 10/23/1984 Sand Plug D 3,755' 3,894' 3,755' 3,894' 59 4 9/28/1973 Fill D 3,939' 4,002' 3,939' 4,002' 4 9/28/1973 Sqz E 4,049' 4,328' 4,049' 4,328' 80 4 9/28/1973 Closed Sleeve F 4,392' 4,778' 4,392' 4,778' 50 4 10/14/1984 Open/partial fill G 4,808' 4,927' 4,808' 4,927' 36 4 9/19/1973 Fill G 5,712' 5032 , 4 9/28/1984 Sqz H 55,,03 162 14 714 4 9/26/1973 Sqz 1 5,766' 5,919' 5,766'5,919' 4 9/26/1973 Sqz 1 5,999' 6,022' 5,999' 6,022' 4 9/16/1973 Plug Updated by DMA 07-05-19 THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Gas Pool, BRU 212-24 Permit to Drill Number: 172-015 Sundry Number: 319-242 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �. a o g c c. a l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Z17�0 Daniel T. Seamount, Jr. Commissioner//' DATED this[ /day of May, 2019. ABDMSi6-/ MAY 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 02019 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 1 ;- 1. 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing Punch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 172-015 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-20037-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A , Will planned perforations require a spacing exception? Yes ElNo 1ZBeluga River Unit 212-24 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0021128 Beluga River/ Undefined Gas* it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (R): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,380' 6,380' - 4,957' 4,957' -311 psi 4,957' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 30" 79' 79' Surface 365 20" 365' 365' 1,530 psi 520 psi Intermediate 3,202' 13-3/8" 3,202' 3,202' 3,450psi 1,950psi Production 6,376' 9-5/8" 6,376'6,376' 6,330psi 3,810psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 2-7/8"; Tubing Grade: 6.5# N-80; Tubing MD (R): 3,095'; See Attached Schematic See Attached Schematic 2-7/8" 6-591 N-80 4,414' Packers and SSSV Type: Otis RDH Dual Pkr; Packers and SSSV MD (R) and TVD (ft): 3,051' MD/TVD; 2 Otis RH Pkrs; N/A 3,923' MD/TVD; 4,373' MD/TVD; N/A -N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 27, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Be York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerfrDhllcoro.com - n (� Contact Phone: 777-8420 •'1 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ I � -2142- 2 11_If+ 2- "Lllf Plug Integrity 13 BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: -ABDMS MAY 15 2019 Post Initial Injection MIT Req'd? Yes No V Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10 .- 1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: GI�1 y� �l 11 10-403 ew 4 017 S•13-11 //�� ////�111 , 1 ♦ `` Approved appli�a4o� Fom the date of approval. Submit Form and ttachments in Duplicate ,Form �Ild_£n�11h6r+1�s R tliimm Alaska, LL Well Prognosis Well: BRU 212-24 Date: 5/8/2019 Well Name: BRU 212-24 API Number: 50-283-20037-00 Current Status: SI Gas Producer Leg: N/A Estimated Start Date: 05/27/2019 Rig: E -line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 172-015 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Surface Pressure: — 70 psi (Short String) Maximum Expected BHP: — 650 psi @ 3,395' TVD (Offsett Well Survey 7-27-12) Max. Predicted Surface Pressure: — 311 psi (Based on .1 psi/ft. gas Grad) Brief Well Summary Well was originally completed as a triple string design with a diesel heater string. First production was 12/28/1978. This was a development well to prove up additional reserves on the North End. WO recompleted the well in 1984 with a dual string in order to locate and isolate water- isolating the Sterling B and the lower Beluga H,I. A coil tbg plug back in 1994 isolated Sterling C and Bel D - scope of work was to CO sand in LS and shut off water in the SS. A sand and cement plug was placed with coiled tbg in SS. The well cum'd over 44 BCF of gas before being shut-in in 2005 from sand production. The SS was making over 5 MMCFD while the LS was struggling to stay online. PX plugs were set in both strings 3,007' LS and 124' SS. The purpose of this Sundry is to set the well up to produce the Sterling A sands through the long string. This 1� will be done by setting a plug deeper and punching the tubing to allow flow up that string. S=f Notes Regarding Wellbore Condition • Min ID in the LS is 2.313". Pre -Sundry Work 1. MIRU Slickline to long string. 2. Pressure test lubricator to 3,000 psi. 3. RIH and pull PX plug @ 3,007'. POOH W/same. 4. RIH With 2.0" GR to 3,310'. POOH W/same. 5. PU tubing plug and RIH and set @ 3,300'. POOH. Wireline Procedure: 6. PU Tubing Punch, RIH in LS and punch tubing @ 3,200'. POOH. 7. RDMO E -line Unit. 8. Turn well over to production to test. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Current Well Head Diagram 0 corn Alesks, LLC RKB to MSL =98' RKB to GL=20.7' 30" 1 20" 2 3 4 TOC @ 3,290' 5 6 7 8 91 10 11 12� 13 P44 P5 ' SCHEMATIC '1° Min I.D. i7 Heater string: 2.375" ;.; Short string: 2.25" EK C B i Long string: 2.205" A Sterling Sands A -C is A Pl' B C D Beluga Sands D-1 9-5/8 TMD=6,380' TVD=3,379' PBMD=4,957' PBTVD=4,958' Max Angle = < 1 deg F EF �F =F �G G �H H Beluga River Unit Well: BRU 212-24 Last Completed: 11/17/1984 PTD: 172-015 API: 50-283-20037-00 CASING DETAIL Size Type WT Grade Conn 10 Btm 30" Conductor 120# 2.31 Weld 32" 79' 20" Surface 94# H-40 Butt 19.124" 365' 13-3/8" Intermediate 68# K-55 Butt 12.415" 3,202' 9-5/8" Prod Casing 43.5# P-110 Butt 8.755" 1,478' 9-5/8" Prod Casing 43.5# N-80 BIRD 8.755" 3,282' 9-5/8" Prod Casing 43.5# S-95 Butt 8.755" 6,376' 2-3/8" Heater String 4.7# W80 8RD 2.441" 1584' TUBING DETAILS 2-7/8" Prod. Short String 6.5# N-80 Butt 2.441" 3,095- 2-7/8" li Prod. Long String 6.5# N-80 8RD 2.441" 4,414' Lone String ID. Depth MD (ft.) ID (in.) Description 1 147 2.313 Otix'X' Nipple 2 2,984 2.31 Brown'CC'Safety Joint 3 3,016 2.313 Otix'XA' Closed Sliding Sleeve 4 3,051 3 Otis RDH Dual Packer 5 3,343 2.5 13 Blast Joints: 6 (3343-3464) & 7 (3621-3760) 6 3,854 2.5 Brown 57k Shear Safety Joint 7 3,887 2.313 Otis'XA' Closed Sliding Sleeve 8 3,923 3 Otis 40k Shear RH Packer 9 4,302 2.5 1 Brown 57k Shear Safety Joint 30 4,337 2.313 Otix'XA' Closed Sliding Sleeve (Closed 9/94) 11 4,373 2.375 Otis 40k Shear RH Packer 12 4,411 2.205 Otis'XN' Nipple (Pulled plug 9/94) 13 4,414 2.36 Otis Shear Sub &TIW Re-entry Guide Short String ID. Depth MD (ft.) ID (in.) Description A 139 2.313 Otix'XNipple B 3,088 2.205 Otis'XN' Nipple C 3092 2.36 Otis Shear Out Sub Heater ID. Depth MD (ft.) ID (in.) 1 Description HA 43 2.375 1 Crossover 2.875"x2.375" Plugs/Fish ID. Depth MD (ft.) ID Date Description P3 3,412 - 9/1/1994 Class G Cement Plug P2 3,624 9/1/1994 20/40 Sand Plug P3 3,752 - 9/1/1994 Fill P4 4,621 - Collapsed 9-5/8" Csg worked w/ swage & csg. Roller P5 4,957 3,436' Plug Set in 1984 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,255' 3,343' 3,255' 3,343' 4 10/21/1984 Sqz A 3,362' 3,436' 3,362' 3,436' 50 4 10/23/1984 open B 3,469' 3,582' 3,469' 3,582' 4 9/29/1973 Sqz C 3,624' 3,752' 3,624' 3,752' 61 4 10/23/1984 Sand Plug D 3,755' 3,894' 3,755' 3,894' 59 4 9/28/1973 Fill D 3,939' 4,002' 3,939' 4,002' 4 9/28/1973 Sqz E 4,049' 4,328' 4,049' 4,328' 80 4 9/28/1973 Closed Sleeve F 4,392' 4,778' 4,392' 41778' S0 4 10/14/1984 Open/partial fill G 4,808' 4,927' 4,808' 4,927' 36 4 1 9/19/1973 1 Fill G 5,032' 55,711246' 32' 5,126' 9/2834 Sqz H 5,162' 5,162' 5,714' 4 /19 728 Sqz 1 5,766' 5,919' 5,766' 5,919' 4 9/26/1973 Sqz 1 5,999' 6,022' 5,999' 6,022' 4 9/16/1973 1 Plug Updated by DMA 05-09-19 KPROPOSED SCHEMATIC HJburp RKB to MSL =98' RKB to GL=20.7' IN HA 30" 1 20" 2 3 Tubing Punches 4 B C TOC @ Tubing Plug @ 3,309 Beluga River Unit Well: BRU 212-24 Last Completed: 11/17/1984 PTD: 172-015 API: 50-283-20037-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30" Conductor 120# 2.31 Weld 32" 79' 20" Surface 94# H-40 Butt 19.124" 365' 13-3/8" Intermediate 68# K-55 Butt 12.415" 3,202- 9-5/8" Prod Casing 43.5# P-110 Butt 8.755" 1,478- 9-5/81, Prod Casing 43.5# N-80 8RD 8.755" 3,282- 9-5/81P Prod Casing 43.5# 5-95 Butt 8.755" 6,376' 2-3/8" Heater String 4.7q N-80 8RD 2.441" 1,584' Min I.D. er Ing an s - I A 1 147 Heater string: 2.375" { C 6' TUBING DETAILS 2.31 tet., Beluga Sands D -I Short string: 2.25" 2-7/8" Prod. Short String 6.5# N-80 Butt 2.441" 3,095' Long string: 2.205" 2-7/8" Prod. Long String 6.5# N-80 8RD 2.441" 4,414' t r S d AC F i P4 Long String 7 F t er Ing an s - I A 1 147 2.313 { C 6' y. 0 2.31 tet., Beluga Sands D -I 3 3,016 8� Otix'XA' Closed Sliding Sleeve q D J E 91 E 30 +. Tubing Plug 11 3,343 12+ F 13 ". F i P4 Brown 57k Shear Safety Joint 7 F P5 G 8 G i H 9 H TMD=6,380' TVD =3,379' PBMD=4,957' PBTVD=4,958' Max Angle = < 1 deg ID. Depth MD (ft.) ID (in.) Description 1 147 2.313 Odx'X' Nipple 2 2,984 2.31 Brown 'CC'Safety Joint 3 3,016 2.313 Otix'XA' Closed Sliding Sleeve 4 3,051 3 Otis RDH Dual Packer 4A 3,300 3,436' Tubing Plug 5 3,343 2.5 13 Blast Joints: 6 (3343-3464) & 7 (3621-3760) 6 3,854 2.5 Brown 57k Shear Safety Joint 7 3,887 2.313 Otis'XA'Closed Sliding Sleeve 8 3,923 3 Otis 40k Shear RH Packer 9 4,302 2.5 Brown57k Shear Safety Joint 30 4,337 2.313 Otix'XA' Closed Sliding Sleeve (Closed 9/94) 11 4,373 2.375 Otis 40k Shear RH Packer 12 4,411 2.205 Otis'XN' Nipple (Pulled plug 9/94) 13 4,414 2.36 Otis Shear Sub &TIW Re-entry Guide Short String ID. Depth MD (ft.) ID (in.) Description A 124 N/A PX Plug Al 139 2.313 Oux'X' Nipple B 3,088 2.205 Otis'XN' Nipple C 3,092 2.36 Otis Shear Out Sub Heater ID. Depth MD (ft.) ID (in.) I Description HA 43 2.375 1 Crossover 2.875"x2.375" Plues/Fish ID. Depth MD (ft.) I ID Date Description P3 3,412 - 9/1/1994 Class G Cement Plug P2 3,624 - 9/1/1994 20/40 Sand Plug P3 3,752 9/1/1994 Fill P4 4,621 - - Collapsed 9-5/8" Csg worked w/ swage & csg. Roller P5 4,957 3,436' Plug set in 1984 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,255' 3,343' 3,255' 3,343' 4 10/21/1984 Sqz A 3,362' 3,436' 3,362' 3,436' 50 4 10/23/1984 open B 3,469' 3,582' 3,469' 3,582' 4 9/29/1973 Sqz C 3,624' 3,752' 3,624' 3,752' 61 4 10/23/1984 Sand Plug D 3,755' 3,894' 3,755' 3,894' 59 4 9/28/1973 Fill D 3,939' 4,002' 3,939' 4,002' 4 9/28/1973 Sqz E 4,049' 4,328' 4,049' 4,328' 80 4 9/28/1973. Closed Sleeve F 4,392' 4,778' 4,392' 4,778' 50 4 10/14/1984 Open/partial fill G 4,808' 4,927' 4,808' 4,927' 36 1 4 1 9/19/1973 1 Fill G 5,032' 5,126' 5,032' 5,126' 4 9/28/1984 Sqz H S,lfi2' 5,714' 5,162' 5,714' 4 9/26/1973 Sqz 1 5,766' 5,919' 5,766' 5,919' 4 1 9/26/1973 Sqz 1 5,999' 6,022' 5,999' 6,022' 4 1 9/16/1973 Plug Updated by DMA 05-09-19 Beluga River 212-24 Current 05/09/2019 Beluga River Unit Tubing hanger, Triple, FMC- BRU 212-24 TC -3C, 11 x 2 7/8 EUE Srd lift 13 3/8 x 9 5/8 x 2 7/8 x 2 7/8 and susp, w/ 2 1/2" type 15 x 2 3/8 BPV profiles, AA trim Tree cap, 2 9/16 3M Triple segmented x 2 7/8 EUE Srd Heater String lift Valve, Swabs, OCr-20, Valve, Swabs, OCr-20, 2 9/16 3M triple segmented2 9/16 3M triple segmen FE, HWO, T-21 V FE, HWO, T-21 Bit Valve, Masters, OCr-20, Valve, Masters, OCT -20, 29/163M triple segmented29/163M triple segmented FE, HWO, T-21 W FE, HWO, T-21 Valve, Masters, OCT -20, OO Valve, Masters, OCT -20, 29/163M triplesegmented 29/163M triple segmented FE, HWO, T-21 FE, HWO, T-21 Tubing head, FMC -TC, 13 5/8 3M x 11 3M, W/ 2- 21/16 SM.S50, BG bottom prep Casing head, CIW-WF, 13 5/8 3M x 13 3/8 SOW, w/ 2- 21/16 5M EFO 13 3/8" LJ 2 7/8" 2 3/8" 10,000,000 1,000,000 100,000 10,000 1,000 100 10 1 Jan -1970 HILCORP ALASKA LLC, BELUGA RIV UNIT 212-24 (172-015) BELUGA RIVER, UNDEFINED GAS Monthly Production Rates Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Produced Gas (MCFM) � GOR —.— Produced Water (BOPM) — - Produced Oil (BOPM) 10,000,000 1,000,000 100,000 10,000 1,000 100 10 1 Jan -2020 SPREADSHEET_1720150_BRU_242-24_Prod-Inject_Curves_Well_Gas_V320_20190510.xlsx 5/10/2019 • • '~+D~c~CC~~~~~~ts TRANSMITTAL Be/uga River Unit deve%pment we//data FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzer ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7"' Ave, Suite 100 Anchorage, Alaska 99501-3539 RE: Beluga River Unit production logging DATE: 08/16/2010 Mail delivery _ _ TransmittE Cook Inlet, Alaska BRU224-13 (permit 173-037-0) ~~ t 4 Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 8/28/2007 proactive Diagnostic Services, Production profile; 7/18/2008 BRU 211-03 (permit 186-010-0) ~pp`~ ~ Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 6/4/2008 ~roactive Diagnostic Services, Gas Entry Survey; 6/5/2008 {rj w ~ ~ .... t, ._ .. yJ 5 P •~ t. BRU 212-35T (permit 198-1.61-0) ~~j(j ~ ~. i/ Proactive Diagnostic Services, Production profile; 7/17/2008 BRU 212-24 (permit 172-015-0) ve Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 9/22/2005 BRU 243-34 (permit 208-079-0) ~~O c~ C~ i~ Proactive Diagnostic Services, Production profile; 9/2/2008 To a//data ~~an ~i~i~ ~,~.~,~~rx~it~ai pia r-email ~o tine e-email :~R. a ~~ ~ l-~t ~,my del®~ CC: Art Co I us, Geologist Receipt: Date: ~~ ~: r~~ ~ ... ,~~~ ... ~ ~~ i'ez:~~~ieai ;~ara s~lar~~ ~, ~en o. ~ s -~ e, ,~la~,'ra ~ ~h:.~L~7 ~?~.~ ~~~~ Sandra D.LsmkeC~Conocvphi//ips com ARCO Alaska(a, Inc. ~ '~ Post Office Ge.., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 12, 1994 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Report of Sundry Well Operations on BRU 212-24 (Approval No. 94-234 and 94-237) Dear Mr. Johnston: During September 8-13, 1994 ARCO Alaska, Inc..successfully completed the proposed water shut-off on string #2 of BRU 212-24. A sand and cement plug was placed with coiled tubing across a watered out Sterling 'C' sand. The well's #2 string was returned to production on September 18, 1994, and has averaged 4 MMcfd with =2 bwpd. Enclosed is a Report of Sundry Well Operations, daily Well Service Reports, and a new well schematic. Please note that two approval numbers were granted for this single well operation and adjust your records accordingly. A copy of each approved Application for Sundry Approval is attached for reference. If you require any further information, do.not hesitate to call Brian Noel at (907) 263-4879. Sincerely, ORIGINAL Tom Wellman BRU/Kuparuk Staff Manager :jls Attachments CC: A. J. Durrani, L. S. Mathis, Shell Western E&P, Inc. Chevron U.S.A., Inc. ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ,% .. STATE OF ALASKA ,~,LASKA OIL AND GAS CONSERVATION CO~v,vllSSION APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon Suspend Operation Shutdown Re-enter suspended well_ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ (~.' -.~ . Off_ 2. Name of Operator ~,RCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4..Location of well at surface 2000' FNL & 50' FWL of'Sec. 24, T13N, R10W, SM At top of productive interval Same.as above - straight hole At effective depth Same as above - straight hole At total depth Same as above - straicjht hole 12. Present well condition summary Total Depth: measured 6380' true vertical 6380' feet Plugs (measured) feet 6. Datum elevation (OF or KB) 98' KB 7. Unit or Property name Beluga River Unit 8. Well number BRU 212-24 9. Permit number 72-015 10. AP! number 50-283-20037-00 11. Field/Pool Belucja River/Sterlinc~ PBTD - 5944' (1973), 4957' (1984 WO) 13. Effective depth: measured true vertical · Casing Length Structural Conductor 7 g' Surface 3 6 5' Intermediate 3 2 0 2' Production 6 3 7 6' Liner Perforation depth: measured Current: See Attached Well true vertical Current: See Attached Well 3400-3900' feet Junk (measured) None 3400-3900' feet Size Cemented Measured depth True vertical depth , 30" Driven 79' 79" 2 0" 535 sxs class G 365' 36 5' 1 3-3/8" 2365 sxs class G 3202' 3202' 9-5/8" 1508 sxs class G 6376' 6376' Schematic Proposed: R ECEI VED schematic Proposed: Tubing (size, grade, and measured dePth Oc PackersDUal stringSand SSSV2'7/8'(type6'5#and measuredN80 tails depth)at 3095' MD (String #2) and 4414' MD (Strir~/a~l~ Oil& 8a$Cot~s' See Attached Well Schematic Al~chnr,, _' Attachments Description summary of proposal _ Detailed operation program X BOP ~etch X, 14. Estimated date for commencing operation Seotember ' 6. 1 c,1~4 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil .._ Gas ;~ Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sit, ned '~"~/~~ Title BRU/KRU Staff Manager Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. ~_ Plug integrity m BOP Test~ Location clearance.._ Mechanical Integrity Tes~0- ~ e~ _. Approved by the order of the Commis ._ -'~-._ Form 10-403 Rev 5/03/89 R E6 E AUG 2 9 1994 Alaska 0ii & Gas Cons. Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other Z. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service Z000' FNL & 50' FWL of Sec. 24, T13N, R10W, SM At top of productive interval Same as above -straight hole At effective depth Same as above - straight hole At total depth Same as above -straight hole 12. Present well condition summary Total Depth: 6380' measured true vertical feet 6. Datum elevation (DF or KB) 6380' feet Plugs (measured) 98' KB 7. Unit or Property name Beluga River Unit 8. Well number BRU 212-24 9. Permit number/approval number 7;>-01 5 / 94-234 & 94-237 10. APl number 50-283-20037-00 11. Field/Pool Beluga River- Sterling PBTD - 5944' (1973), 4957' (1984 WO) Sand (3923-3600') / Cement (3600-341 Effective depth: measured 3400-3900' feet true vertical 3400-3900' feet Junk (measured) None Casing Length Size Structural Conductor 79' 30" Surface 365' 20" Intermediate 3202' 13-3/8" Production 6376' 9-5/8" Liner Perforation depth: measured Cemented Measured depth True vertical depth Driven 79' 79' 535 sxs class G 365' 365' 2365 sxs class G 3202' 3202' 1508 sxs class G 6376' 6376' See Attached Well Schematic ORIGINAL true vertical See Attached Well Schematic Tubing (size, grade, and measured depth) Dual strings 2-7/8" 6.5#, N-80 tails at 3095' MD (string #2) and 4414' (string #1 ) Packers and SSSV (type and measured depth) See Attached Well Schematic 13. Stimulation or cement squeeze summary RECEIVED u tT 2 4 String #Z (tubing x casing annulus) water shut off plug (all depths RKB): Formation sand fill (3923-3744'), 20/40 Sand (3744-3600') Cement (3600-341Z') 12.3 bbls (60 sx) neat class G Ala~l~ Oil & Gas Cons. Co. miIIL~IoI1 ~ohorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1000 est. 960 0 850 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 4000 2 0 1110 16. Status of well classification as: Oil Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~tned ~ Uc)~~ Title Beluga / Kuparuk Staff Manager Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ',ARCO Alaska Inc. BRU 212-24 Spud Date: 8/19/73 Last Compl: 11/84 Schematic Rev: 10/11/94 NE 1/4 34, T13N, R10W f eluga River Unit APl#: 50-283-20037-00 Original RKB (Depth Ref): 98' Ground Level: 77.3' Maximum Hole Angle: <1 ° Angle at Perforations: < 1 ° Well Type: Gas Producer Annulus Fluid: Gas Top of Stealing: ASP: 2633630,323388 Dual w/heater string Jewelry Depth Length EauiDment 1 147' 1 .,50' Otis "X" Nipple 2 2983" 104.' Brown "CC" Safety Jt. 3 3016" 3.14' Otis "XA" Sleeve 4 3051' 8.00' Offs RDH Dual Pkr. I.D. O.D. 2.313" 3.25" 2.31" 3.69" 3.0" 8.38" · k 5 3343' 121' 6 Blast Joints 2.5" 3.69" 6 3621' 139' 7 Blast Jonts 2.5" 3.69" 7 3854" 2.50' Brown Safety Jt. 57M # Shear' 2.5" 3.75" 8 3887' 3.14' Otis "XA" Sleeve 2.313" 3.75 9 3923' 4.93' Offs RH Pkr. 40M # Shear 3.0" 8.38" 10 4302' 2.50' Brown Safety Jt. 57M # Shear 2.5" 3.75 ' 11 4337". 3.13" Offs "XA" Sleeve ¢Closed 9/94) 2.313" 8.38" 12 4373 4.93" Offs RH Pkr. 40M # Shear 2.375" 3.5" 13 4411' 1.30" Otis "XN" Nipple (pulled plug 9/94) 2.205" 3.25" · · 14 4414' T.I.W. Re-entry 2.375" 3.5" A 139' 1.50' Otis "X' Nipple R ECEi~ 1~-.U.313" 3.25" 5 B 3091' 1.28' Otis 'XN' Nipple ·'- 2.205" 3.5' AA Casi147-ndl'20'nga Tu Otis "X" Nipple 0C~~-~ ~0JcJ4 6 i~iiii:~iiiii~iiiiiii~i!i Ot[ & Gas Cons Co ::::::::::::::::::::::::::?::::::::: °ar~e T o D om Surface 20" 94# - H-40 7 Intermediate 13 3/8" 68# K-55 Butt 3202' 8 Prod. Casing 9 5/8" 43.5~ P-110,S-95,N-80 8RD/Butt 6376' Prod. Tubing 2 7/8" (1) 6.5# N-80 8 R D 4414' 9 Prod. Tubing 2 7/8" (2) 6.5# N-80 Butt 3095' Heater String 2 3/8" (3) 4.7# N-80 8 RD 1584' Notes: Collapsed 9-5/8" casing (4621 '-4626') worked w/swage & csg. roller during 1973 completion G String #2 - Formation fill (3923-3744'), 20/40 sand (3744-3600% class cmt (3600-3412') RKB 10 11 Perforations Net ~ 12 Zone ~ Density E~ Interval Status 13 A 3255'-3343' 4 Sqz Closed 3362'-3412' ~ 4 50' String 2 Open 14 B 3469'-3582' 4 Sqz Closed C 3624'-3752' 4 Sand Plug String 2 Closed 9/94' D 3755'-3894' 4 Sand Plug String 2 Packer Closed 9/94 , TD 6380' 3939'-4002' 4 Sqz Closed E 4049'-4328' 4 80' String 1 · Packer Closed 9/94 F 4392'-4778' 4 50' String 1 Open 9/94 G 4808'-4927' 4 36" String 1 Open 9/94 Taa Data - Post 9/94 CTU Work 5/7/91 CT-l-fL, XN at 3091' RKB 6/13/94 CT, TOC at 3412' RKB ~;tring 1 6/20/92 1.75" bailer, fill at 4684' RKB 9/1 1/94 CT, fill at 4779' CTD 9/19/94 2" LIB, fill (bridge?) at 4609' WLM 10/11/94 KEMARK~ IU ,I./. Ho I.~r~ou · I". ~ WELL SERVICE REPORT ~ct 3¥/?.' / OCT Z 4 13~4 J'-J CHECK THIS BLOOK IF SUMMARY CONTINUED ON BAOK Repm'tW"lher J T~mp, 'F ChlII'F"M~' JvI"IbilIty'F ,.ii. JVand V.I. · _ _ Aia~<a Oil & Gas Cons. Commission Anchorage TOTAL P.04 x SEP-14-1c~D4 I~: 48 FFL~H BELUGA RIUER TO ARCo Alaska, Inc';~ ~djIIMdlary of AU~ntic Richfield C, ml'qMiny WELL REMARKS D. I:1. Gr'ou · P. 0~ WELL SERVICE REPORT O~EI~TION AT REI~RT TIME ~:;~-' .., _~ ...... · 0 7:..?'e - ~CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK mil# Vel. knot~ Jalgned . ' SEP-14-1994 85:49 FROM BEL~ RIUER TO D.A.Groue P.O~ 'REMARKS CONTINUED: · ,~ _~/~,~. ~-~L,/-~ _z,,~-~, ~,, ,~,.z ~_~,.~-..' ~_ ~__~_ · .T¥~s' ,,t' Zo?. ~'//~'/,.,~ ) u-,,,.// _~:/,,,/~? /, z .~_,.,. DE6GRIPTION DALLY ACCUM. TOTAL cAMco __ OTIS ~H~M~GER DRESSER.ATI.~S ii iii HALUBU~ON ., ARCTIC COIL TUBING ..... FRACMASTER , i B. J. HUGHES , i i i i i1 · , 111 Roustabouts Diesel ........... , i i · i i M~t~ol Su~wlsion ! ! ! ! · . . Pre. Job Safety Meeting AFE ........... .. , , · __ · . i i i i1.. i i i · E~P-14-1~4 1~l~:47 PKqJFI UI:.LUL~ ,- ARCO Alaska, Inc.,~ CONTRACTOR REMARKS iu WELL SERVICE REPORT OPERATION AT REPORT TIME · ii , i , CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK UCT 24 '~' Alaska Oil & Gas I~bns. Uommissiu,' ' SEP-12-1994 F~OM BEL~ RIUER ARCO Alaska, Inc. Sul~ldi~ry of Atl&r~llc Richfield ~y ..... TO D.A.G~oue P. Et3 WELL SERVICE REPORT FIEI,,O ,.D~_ TRi(;;¥- ~TATE ,,,~ ,- ~ E?. ~ 6,4' ,~'> '" e='~ OPERATION AT 'REPORT TIME [""[ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WMrlhm' I T. mp. Chlll. F~r l'~/I.Ibiilly IWind V.I. I~ned Rep, m't *F 'F miles __ kno~ "~. TOTAL P.03 SEP-12-1994 El6:16 FROM BELUGA RIUER ARCO AlaSka,'lnc. Sul~tdlm7 of Ml&ntlc RiehfiM~ TO D.A. ~roue P. WELL SERVICE REPORT I FIELD- QI~.I~ICT- STATE /~ |OPERATION AT REPORT TIME _ I _.. _~;t o., CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~ I"'"'', i'"' "-"1"~ '/'~"-' ARCOAlaska; Inc.~-~ REMARKS ./ WELL SERVICE REPORT co;/. i · · ~'~~L~ ..~ .,.~.../,;.~ '~o /zoo ,,,,.. . _ · , i · i _ i [~HEcK THIS BLOCK IF SUMMARY CONTINUED,~ c~/q/gV' ..... We.therReport tveml)' 'F C~illFil=i~vlVi$ibllit~ miles I ARCO Alaska, Inc~. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 25, 1994 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Re: Submittal of Application for Sundry Approval to shut off water on BRU 212-24 Dear Mr. JohnstOn· Attached is an Application for Sundry Approval to shut off a watered out Sterling C sand on BRU 212-24 to return string #2 to production. The water zone was identified by neutron and water flow logs run in June of this year. Water rates of bwph (960 bwpd) prevent prOduction of the short string completion. Since there are no future plans for a rig workover of the well, a coiled tubing unit will be used to place a sand/cement plug across the lower perforations of the #2 string completion. Although this procedure precludes the future pulling of some completion equipment, it will not prevent obtaining zonal isolation during the final P&A. The deeper zones of string #1 can still be squeezed with coiled tubing and then the upper part of the well pulled and conventionally plugged. Please refer to the attached procedure and well schematic for details of the water shut off operation. If you require any further information, do not hesitate to call Brian Noel at (907) 263-4879. Sincerely, Tom Wellman BRU/Kuparuk Staff Manager :jls Attachments CC' A. J. Durrani, L. S. Mathis, RECEIVED /~/aska Oil & Gas Cons. Cor~ission Shell Western E&P, Inc. Chevron U.S.A., Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA AI~S~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate __ Change approved program _ Pull tubing _ Variance _ Perforate __ Other Water Shut Off_ 2. Name of Operator ~,RCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service _ 6380' true vertical 6380' Effective depth: measured 3400-3900' true vertical 3400-3900' Casing Le n gt h Size Structural Conductor 7 9' 3 0" Surface 3 6 5' 2 0" Intermediate 3202' 1 3-3/8" Production 6376' 9-5/8" Liner Perforation depth: measured Current: See Attached Well Schematic Proposed: true vertical Current: See Attached Well schematic Tubing (size, grade, and measured depth 4.. Location of well at surface 2000' FNL & 50' FWL of Sec. 24, T13N, R10W, SM At top of productive interval Same as above - straight hole At effective depth Same as above - straight hole At total depth Same as above - straight hole 12. Present well condition summary Total Depth: measured 6. Datum elevation (DF or KB) 98' KB 7. Unit or Property name Beluga River Unit 8. Well number BRU 212-24 9. Permit number feet Plugs (measured) feet feet Junk (measured) feet Cemented Driven 535 sxs class G 2365 sxs class G 1508 sxs class G Proposed: 13. 72-015 10. APl number 50-283-20037-00 11. Field/Pool Belucja River/Sterlincj PBTD - 5944' (1973), 4957' (1984 WO) None Measured depth True vertical depth 79' 79' 365' 365' 3202' 3202' 6376' 6376' ORIGINAL Dual strings 2-7/8" 6.5# N80 tails at 3095' MD (String #2) and 4414' MD (String #1) Packers and SSSV (type and measured depth) See Attached Well Schematic Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation Se_member ' 6. 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas ~[ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "'~~~ Title BRU/KRU Staff Manager FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test _ Subsequent form ~,pproved by the order of the Commission Form 10-403 Rev 5/03/89 0rigir{~~~y r)avid W.~,~)~s~:~i require Approved Copy Returned 10- ~/O4 IApproval No. ~Z~..-<~,~? I Commissioner Date e//"/~ ~ SUBMIT IN TRIPLICATE RECEIVED AUG 2 9 1994 Alaska Oil & Gas Cons. Commission CT Sand/Cement Plug BRU 212-24-2 BR 42 August 25, 1994 ()b_iective.~: Place sand in tubing x casing annulus to cover watered out sand perfs at 3624-3636' MD. Lay in = 150' cement to cap sand plug (TOC no higher than 3420' MD). Flow test remaining A sand peris after WOC. · Current Status: BRU 212-24 currently has both strings shut in. String #1 was SI 3/93 due to sand in tubing from the D/E sands (sleeve opened 6/92). Attempts to bail sand with slickline and close the sleeve in June and August 1993 were unsuccessful. A coiled tubing clean out is planned (BR 41) to return well to production from the F/G sands. String #2 was SI 4/91 due to high rate water production. After the 1984 workover to isolate and squeeze water zones, the string produced from 3-5 MMcfd until water reappeared in early 1991. Water rates averaged from 30-70 bwpd and the string was SI in 4/91. A test in 10/91 confirmed high water rates (estimated 276 bwpd) at FTP <1000 psig and the well was SI until the summer of 1994. TDT and WFL logs run in 6/94 with the well SI and also flowing (=850 psig FTP and 40 bwph - 960 bwpd) identified the open C sand perfs from 3624-3636' MD as the water source. Other squeezed intervals appeared to be holding. Due to the down dip water bearing Sterling intervals and the Beluga sand production problems, plus the previous workover's extensive squeeze work and collapsed casing, there is no future rig workover planned for this well. If the water interval can be shut off by placing a sand/cement plug on top the packer at 3923' MD, the Sterling A sand perforated from 3362-3414' MD is still gas bearing and has the potential to produce 4+MMcffi. Last Tag: String #2 'XN' profile at 3091' KB - 6/2/93 Pressures: String #2 11 psig SITP- 4/1/94 with fluid level at 2' MD 1180 psig SITP - 4/1/94 with fluid level at 2940' MD 1260 psig SITP- 3/90 deliverability test Min. ID: String #2 2..205" Otis 'XN' nipple at 3091' KB Wellhead: 3000# tree 2-9/16" FMC valves Tubing: 2-7/8" String #2 Casing: %5/8" Tubing x casino= annulus: ID - 2.441" ID - 8.755" 0.00579 bbls/ft 0.0744 bbls/ft 0.0664 bbls/ft Coil tubing 1- I/2" 2-7/8" tbg x 1-1/2" annulus' ID -1.282" 0.0016 bbls/ft 0.0036 bbls/ft RECEIVED AU(; 29 1994 Alaska Oil & Gas Cons. Commission BRU 212-24-2 BR 42- CT Sand/Cement Plug August 25, 1994 Wellsite Preparation anti Safety: o · Rig up choke skid and Baker tank to take returns from coiled tubing's pump-in sub to be rigged up on string #2. Position tank downwind (contactor side of pad?) fi.om well house. Place wind sock on Baker tank and/or well house. Pressure test connections per wellsite supervisor's directions. Install pressure gauges up and down stream of choke. Fill Baker tank with =250 bbls of clean water from storage tank set up at Enstar pad's water well. MIRU coiled tubing, filtering and pumping equipment, 75 bbl batch mixer, and CEA's 50 ton crane. RU riser, pump-in sub, and BOPE stack on string #2 (tree cap has 2 7/8" EUE 8rd threads). . Manifold surface flowlines so that water can be pulled either from Baker tank or from vac truck and run through filtering equipment before being pumped to coil. Use 75 bbl batch mixer for sand placement and cementing. 4. Test all high pressure lines to 4000 psi per wellsite supervisor's instructions. o Before beginning operations discuss procedure and hold a safety meeting with all personnel involved. Shut off any unnecessary equipment. Record pressures of both tubing strings and the production casing on WSR. Procedure: . Roll Baker tank volume to mix in 2% KCI (7 ppb) and J-313 friction reducer (0.02 gal/bbl - 0.04% by volume). . RIH with CT with hydraulic disconnect, tubing tail locator, check valve and mule shoe. Check pick up weight while RIH and slow down when passing through jewelry. o Tie in with tubing tail and adjust depth counter as required. Proceed slowly in the casing x 2-7/8" tubing annulus and tag packer at 3926' MD. Note: No record of sand production was found, but there may be some fill on top of packer (depth of lowest perforation is 3894' MD). Ensure that a tag above packer is hard fill and not a bridge. . After tagging packer, note depth and begin sand plug placement. Lay in sand in 3 stages. Adjust last stage's volume as needed for desired top of sand (TOS) at --3570' MD. Mix 20/40 sand in 75 bbl batch mixer at 3 ppg. Note: Annular volume from packer at 3926' MD to TOS at 3570' MD is 23.6 bbls. (14,000. lbs. of 20/40 sand (--39 # sand/fO in = 116 bbls of brine @ 3 ppg). Stage 1' Stage 2' Stage 3' 40 bbls w/5000# sand 40 bbls w/5000# sand --32 bbls w/4000# sand 128' est. TOS = 3798' 128' est. TOS = 3670' 102' est. TOS-- 3568' RECEIVED AUG 2 9 1994 Alaska Oil & Gas Cons. Commission Anchorage BRU 212-24-2 BR 42- CT Sand/Ccnlcnt Plug August 25, 1994 10. 11. 12. 13. 14. 15. 16. If KCI water is unable to carry sand, mix sand with 1/3 ppb Xanvis in batch mixer. Have lithium hypochlorite (bleach) available as a breaker (BHT is =100 °F) to minimize settling time. Pump at maximum rate possible and hold =800 psi back pressure on CT x 2-7/8" annulus to minimize returns while laying sand. POOH with coil at same rate as sand fill uP (pump rate of 1 bpm of 3 ppg slurry = 126 g sand/min = 3.5 ft/min of fillup). Chase sand with KCI water (CT volume is 24 bbls) and once sand clears mule shoe, pull up into production tubing above the No-Go profile at 3094' MD and allow sand to settle. Prior to pumping next stage, run out 2-7/8" tubing tail with CT and tag TOS. Pick up 50' and pressure up to 1500 psi to bump sand top and knock out any bridges. Tag TOS again and then pump second stage as in step gl0. POOH above No-Go and allow sand to settle. Bump sand top with pressure as above and obtain TOS depth. Size third stage's volume to bring TOS to =3570' MD and pump as before. Displace sand to mule shoe with 24 bbl KCI water. POOH with CT and pick up cementing nozzle. Rinse sand from batch mixer and flush surface lines. Allow enough time for sand plug to settle before pumping cement plug. RIH with cementing nozzle and tag sand plug top. Mix neat G cement per attached specification sheet, using clean water from vac truck. Note: Annular volume from TOS at =3570' MD to 3420' MD is 10 bbls. Adjust cement volume so that TOC will be no higher than 3420' MD. Lay in cement on top of sand. Displace cement to nozzle with 24 bbls KCI water. Keep nozzle below top of cement while pumping and pull out of hole at same rate as fill up (=3 ft/min for I bpm). Once cement clears nozzle, pull into 2-7/8" tubing, flush CT and continue to circulate while POOH. 17. Rig down CT from string g2 and rig up on string gl for fill clean out. Note: After completing work on string gl, rig up on string g2, Rill and tag TOC. If additional cement is required, a procedure will be provided. Drawdown guidelines for flow testing the interval will also be forwarded. 18. Send copy of WSR and daily cost estimates to Brian Noel, ATO-1282. RECEIVED AUG 2 9 1994 A!~.ska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. I . BRU"' 212-24 Spud Date: 8/19/73 Last Compl: 11/84 Schematic Rev: 12/1/93 NE 1/4 34, T13N, RIOW Beluga River Unit APl#: 50-283- 7-C Original RKB (Depth Ref): 98' Ground Level: 77.3' Maximum Hole Angle: < l° Angle at Perforations: < 1 ° Well Type: Gas Producer Annulus Fluid: Gas Top of Sterling: ~ 2633630,323388 Dual w/heater string 1 Jewelry 1 147' 1.50' 2 2983' 104.' 3 3016' 3.14' 4 3051' 8.00' 5 3343' 121' 6 3621' 139' 7 3854' 2.50' 8 3887" 3.14' 9 3923' · 4.93' 10 4302' 2.50' 11 4337' 3.13' 12 4373' 4.93' 13 4411' 1.30' 14 4414' Otis "X* Nipple Brown "CC" Safety Jt. Offs 'XA* Sleeve Offs I~DH Dual Pkr. 6 Blast Joints 7 Blast Jonts Brown Safety Jt. 57M ~ She¢~ Offs "XA" Sleeve Oils RH Pkr. 40M ~ Shear Brown Safety Jt. 57M ~ Shear Offs "XA" Sleeve ~ Otis RH Pla'. 40M ~ Shear Offs "XN* Nipple J~ T.I.W. Re-entry 2.313' 3.25' 2.31' 3.69" 3.0" 8.38' 2.5" 3.69" 2.5" 3.69' 2.5' 3.75' 2.313" 3.75 3.0' 8.38" 2.5' 3.75 2.313' 8.38' 2.375' 3.5' 2.205' 3.25' 2.375' 3.5' A 139' 1.50' ~e~,,e,~~ B 3091' 1.28' ¢~' AA 147' 1.20' · '~c Casing and Tubing Surface 20" Intermediate 13 3/8" Prod. Ca~ng 9 5/8' Prod. Tubing 2 7/8" (1) Prod. Tubing 2 7/8" (2) Heater Siting 2 3/8" (3) Otis "X" Nipple Offs "XN* Nipple Otis "X* Nipple 94# H-40 Buff' 68~ K-55 Bult 43.5~ P- 110,S-95,N-80 8RD/Butt 6.5~ N-80 8RD 6.5~ N-80 Butt 4.7~ N-80 8RD 2.313" 3.25' 2.205' 3,5" Bottorl'l 365' 3202' 6376' 4414' 3095' 1584' Collapsed 9-5/8" casing (4621 '-4626') worked w/swage & csg. roller during 1973 completion 10 11 12 13 14 Perforations A 3255"-3343' 4 Sqz Closed 3362'-3436' 4 6(7 String 2 Open B 3469"-3582' 4 Sqz Closed C 3624'-3752' 4 61' String 2 Open D 37~,~'-3894' 4 ~9" ~trina 2 Packer aden 3939"-4[]02' 4 SClz Closed E 4049"-4328' 4 80' String 1 Packer Open 6/92 F 4392'-4778' 4 50' String 1 Closed 6/92 G 4808'-4927' 4 36' String 1 Closed 6/92 5/7/91 2.3" GR, XN at 3091' RKB 6/2/93 2.3" GR, XN at 3091' RKB 2/23/90 1.75" bailer, fill at 4808' RKB 1/11/91 1.75" bailer, fill at 4709' WI.M 5/7/91 1.5" bailer~ fill at 4677'RKB 6/20192 1.75" bailer, fill at 4784' RKB 8/17/94 AUG 2 9 1994 Gas Cons. Commission Anchor~e COILED TUBING BOPE LUBRICATOR BLIND RAMS SHEAR RAMS SLIP RAMS 4--..-- .RISER PIPE RAMS Z-7/$" EUE 8RD TREE CONNECTION Swab Valve Double Master Valves Wellhead ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 25, 1994 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Submittal of Application for Sundry Approval to shut off water on BRU 212-24 Dear Mr. Johnston: Attached is an Application for Sundry Approval to shut off a watered out Sterling C sand on BRU 212-24 to return string #2 to production. The water zone was identified by neutron and water flow logs run in June of this year. Water rates of 40 bwph (960 bwpd) prevent production of the short string completion. Since there are no future plans for a rig workover of the well, a coiled tubing unit will be used to place a sand/cement plug across the lower perforations of the #2 string completion. Although this procedure precludes the future pulling of some completion equipment, it will not prevent obtaining zonal isolation during the final P&A. The deeper zones of string #1 can still be squeezed with coiled tubing and then the upper part of the well pulled and conventionally plugged. Please refer to the attached procedure and well schematic for details of the water shut off operation. If you require any further information, do not hesitate to call Brian Noel at (907) 263-4879. Sincerely, Tom Wellman BRU/Kuparuk Staff Manager :jls Attachments CC: A. J. Durrani, L. S. Mathis, Shell Western E&P, Inc. Chevron U.S.A., Inc. RECEIVED AUG 2 6 1994 ~,~aska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Pull tubing_ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension _ Stimulate ~ Variance_ Perforate_ Other Water Shut Off_ 6. Datum elevation (DF or KB) 2. Name of Operator Change approved program _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2000' FNL & 50' FWL of Sec. 24, T13N, R10W, SM At top of productive interval Same as above - straight hole At effective depth Same as above - straight hole At total depth Same as above - straight hole 12. Present well condition summary Total Depth: measured true vertical ORIGINA Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: 6380' feet Plugs (measured) 6380' feet 3400-3900' feet Junk (measured) 3400-3900' feet 98' KB 7. Unit or Property name Beluga River Unit 8. Well number BRI, I, 212-24 9. Permit number 72-015 10. APl number · 130-283-20037-00 1 . Field/Pool Beluga River/Sterling Current' PBTD - 5944' (1973), 4957' (1984 we) None Length Size Cemented Measured depth True vertical depth 79' 30" Driven 79' 79' 3 65' 2 0" 535 sxs class G 365' 3 6 5' 3202' 1 3-3/8" 2365 sxs class G 3202' 3202' 6376' 9-5/8" 1508 sxs class G 6376' 6376' measured RE£EIVED See Attached Well Schematic Proposed: true vertical AUG 2 6 1994 See Attached Well Schematic Proposed: Tubing (size, grade, and measured depth A Dual strings 2-7/8" 6.5# NS0 tails at 3095' MD (String #2) and 4414' MD (String #1)laska 0ii & Gas Cons. Comlaj~i~ Anchorage Packers and SSSV (type and measured depth) See Attached Well Schematic 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch X, 14. Estimated date for commencing operation September 6, 199_4 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned Title BRU/KRU Staff Manager FOR COMMISSION USE ONLY Date Conditions of approval' Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission original Signed By DaVid W. Johnston 10- Commissioner Form 10-403 Rev 5/03/89 IApproval__.No.~, ..,9 ./ SUBMIT IN TRIPLICATE Approved Copy Returned _ Form 3160-5 (November 1983) (Formerly 9-331) UNITED STATES Submit in Triplicate' DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT Form approved. Budget Bureau No. 1004-0135 Expires August 31, 1985 SUNDRY NOTICES AND REPORTS ON WELLS 5. Lease designation and serial no. (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. ADL-21128 Use "APPLICATION FOR PERMIT--" for such proposals.) 1. Oil Gas 6. If Indian, Allottee or Tribe Name Well Well X Other 2. Name of Operator 15. Elevations (Show whether DF, RT, GR, etc.) 98' KB 7. Unit Agreement Name Beluga River Unit 8. Farm or Lease Name ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorac~e, AK 99510 4. Location of well (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface: 2000' FNL, 50' FWL, Sec. 24, T13N, R10W, SM At Total Depth Same as above - straight hole 14. Permit No. 72-015 9. Well number BRU 212.24 APl# 50-283-20037-00 10. Field and Pool, or Wildcat Beluga Ri~/er Field / Sterling 11. Sec., T., R., M., or BLK, and Survey or Area Sec. 24, T13N, R10W, SM 12. County or Parish ~ 13. State Kenai I AK 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Notice of Intention to: Test Water Shut-Off m Pull or Alter Casing Fracture Treat w Multiple Complete Shoot or Acidize Abandon' Repair Well ~ Change Plans (Other) Water Shut Off 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Subsequent Report of: Water Shut-Off ~ Repairing Well t Fracture Treatment __ Altering Casing t Shooting or Acidizing m Abandonment ~ (Other) Note: Report results of multiple completion on Well Completion or Recomptetion Report and Log form.) )ertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)' ARCO Alaska, Inc. proposes to isolate a watered out Sterling C sand (=960 bwpd). The high water rate prevents production from the #2 string, which is also completed in the Sterling A. Coiled tubing will be used to set a sand and cement plug over the Sterling C and earlier squeezed B perforations. A detailed procedure and well schematic are attached. RECEIVED AUG 2 G 1994 Alaska Oil & Gas Cons. Commission Anchorage 18. I hereby certify that the foreg~n~ is true and correct SIGNED '~¢'~'~/~'"~TITLE Beluga/Ku~aruk Staff Manager , I(This TITLE space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: DATE DATE *See Instructions on Reverse Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. CT Sand/Cement Plug BRU 212-24-2 BR 42 August 25, 1994 Objectives: Place sand in tubing x casing annulus to cover watered out sand perfs at 3624-3636' MD. Lay in =150' cement to cap sand plug (TOC no higher than 3420' MD). Flow test remaining A sand perfs after WOC. · ~llrrcnt Status: BRU 212-24 currently has both strings shut in. String #1 was SI 3/93 due to sand in tubing from the DAE sands (sleeve opened 6/92). Attempts to bail sand with slickline and close the sleeve in June and August 1993 were unsuccessful. A coiled tubing clean out is planned (BR 41) to return well to production from the F/G sands. String #2 was SI 4/91 due to high rate water production. After the 1984 workover to isolate and squeeze water zones, the string produced from 3-5 MMcfd until water reappeared in early 1991. Water rates averaged from 30-70 bwpd and the string was SI in 4/91. A test in 10/91 confirmed high water rates (estimated 276 bwpd) at FTP <1000 psig and the well was SI until the summer of 1994. TDT and WFL logs run in 6/94 with the well SI and als() flowing (=850 psig FTP and 40 bwph - 960 bwpd) identified the open C sand perfs from 3624-3636' MD as the water source. Other squeezed intervals appeared to be holding. Due to the down dip water bearing Sterling intervals and the Beluga sand production problems, plus the previous workover's extensive squeeze work and collapsed casing, there is no future rig workover planned for this well. If the water interval can be shut off by placing a sand/cement plug on top the packer at 3923' MD, the Sterling A sand perforated from 3362-3414' MD is still gas bearing and has the potential to produce 4+MMcfd. Last Tag: String #2 Pressures: String #2 Min. ID: String #2 Wellhead: 3000# tree Tubing: 2-7/8" String Casing: 9-5/8" Tubing x casing annulus: Coil tubing 1-1/2" 2-7/8" tbg x 1-1/2" annulus: 'XN' profile at 3091' KB - 6/2/93 11 psig SITP - 4/1/94 with fluid level at 2' MD 1180 psig SITP - 4/1/94 with fluid level at 2940' MD 1260 psig SITP- 3/90 deliverability test 2.205" Otis 'XN' nipple at 3091' KB 2-9/16" FMC valves #2 ID - 2.441" ID - 8.755" 0.00579 bbls/ft 0.0744 bbls/ft 0.0664 bbls/ft ID- 1.282" 0.0016 bbls/ft 0.0036 bbls/ft RECEIVED ^taska Oil & (las Cons. Anchorage BRU 212-24-2 BR 42- CT Sand/Cement 'Plug August 25, 1994 Weilsite Preparation and Safety' . Rig up choke skid and Baker tank to take returns from coiled tubing's pump-in sub to be rigged up on string #2. Position tank downwind (contactor side of pad?) from well house. Place wind sock on Baker tank and/or well house. Pressure test connections per wellsite supervisor's directions. Install pressure gauges up and down stream of choke. Fill Baker tank with =250 bbls of clean water from storage tank set up at Enstar pad's water well. MIRU coiled tubing, filtering and pumping equipment, 75 bbl' batch mixer, and CEA's 50 ton crane. RU riser, pump-in sub, and BOPE stack on string #2 (tree cap has 2 7/8" EUE 8rd threads). o Manifold surface flowlines so that water can be pulled either from Baker tank or from vac truck and run through filtering equipment before being pumped to coil. Use 75 bbl batch mixer for sand placement and cementing. 4. Test all high pressure lines to 4000 psi per wellsite supervisor's instructions. o Before beginning operations discuss procedure and hold a safety meeting with all personnel involved. Shut off any unnecessary equipment. Record pressures of both tubing strings and the production casing on WSR. Procedure: o Roll Baker tank volume to mix in 2% KCI (7 ppb) and J-313 friction reducer (0.02 gal/bbl - 0.04% by volume). . RIH with CT with hydraulic disconnect, tubing tail locator, check valve and mule shoe. Check pick up weight while RIH and slow down when passing through jeweh'y. o Tie in with tubing tail and adjust depth counter as required. Proceed slowly in the casing x 2-7/8" tubing annulus and tag packer at 3926' MD. Note: No record of sand production was found, but there may be some fill on top of packer (depth of lowest perforation is 3894' MD). Ensure that a tag above packer is hard fill and not a bridge. . After tagging packer, note depth and begin sand plug placement. Lay in sand in 3 stages. Adjust last stage's volume as needed for desired top of sand (TOS) at =3570' MD. Mix 20/40 sand in 75 bbl batch mixer at 3 ppg. Note: Annular volume from packer at 3926' MD to TOS at 3570' MD is 23.6 bbls. (14,000 lbs. of 20/40 sand (=39 # sand/ft) in = 116 bbls of brine @ 3 ppg). Stage 1' S rage 2: Stage 3: 40 bbls w/5()()(gt sand 40 bbls w/5000g sand =32 bbls w/4000# sand 128' est. TOS = 3798' 128' est. TOS = 3670' 102' est. TOS = 3568' RECEIVED AUG 2 6 1994 Alaska Oil & Gas Cons. Commission Anchora.qe BRU 212-24-2 BR 42- CT Sand/Cemel. Plug August 25, 1994 10. 11. 12. 13. 14. 15. 16. If KCI water is unable to carry sand, mix sand with 1/3 ppb Xanvis in batch mixer. Have lithium hypochlorite (bleach) available as a breaker (BHT is = 100 °F) to minimize settling time. Pump at maximum rate possible and hold =800 psi back pressure on CT x 2-7/8" annulus to minimize returns while laying sand. POOH with coil at same rate as sand fill up (pump rate of I bpm of 3 ppg slurry = 126 g sand/rain = 3.5 ft/min of fillup). Chase sand with KCI water (CT volume is 24 bbls) and once sanc'l clears mule shoe, pull up into production tubing above the No-Go profile at 3094' MD and allow sand to settle. Prior to pumping next stage, run out 2-7/8" tubing tail with CT and tag TOS. Pick up 50' and pressure up to 1500 psi to bump sand top and knock out any bridges. Tag TOS again and then pump second stage as in step gl0. POOH above No-Go and allow sand to settle. · Bump sand top with pressure as above and obtain TOS depth. Size third stage's volume to bring TOS to =3570' MD and pump as before. Displace sand to mule shoe with 24 bbl KCI water. POOH with CT and pick up cementing nozzle. Rinse sand from batch mixer and flush surface lines. Allow enough time for sand plug to settle before pumping cement plug. RIH with cementing nozzle and tag sand plug top. Mix neat G cement per attached specification sheet, using clean water from vac truck. Note: Annular volume from TOS at =3570' MD to 3420' MD is 10 bbls. Adjust cement volume so that TOC will be no higher than 3420' MD. Lay in cement on top of sand. Displace cement to nozzle with 24 bbls KC1 water. Keep nozzle below top of cement while pumping and pull out of hole at same rate as fill up (=3 ft/min for 1 bpm). Once cement clears nozzle, pull into 2-7/8" tubing, flush CT and continue to circulate while POOH. 17. Rig down CT frown string g2 and rig up on string gl for fill clean out. Note: After completing work on string gl, rig up on string g2, RIH and tag TOC. If additional cement is required, a procedure will be provided. Drawdown guidelines for flow testing the interval will also be forwarded. 18. Send copy of WSR and daily cost estimates to Brian Noel, ATO-1282. RECEIVED AUG 2 6 1994 Alaska Oil & Gas Cons. Commission Anchoratle · ARCO'Alaska, Inc. BRU 212-24 Spud Date: 8/19/73 Last Compl: 11/84 Schematic Rev: 12/1/93 NE 1/4 34, T13N, R10W Beluga River Unit APt : 50-283-2[X 7-00 Original RKB (Depth Re0: 98' Ground Level: 77.3' Maximum Hole Angle: <1° Angle at Perforations: < 1 ° Well Type: Gas Producer Annulus Fluid: Gas Top of Sterling: ~ 26,t36,t0,323388 Dual w/heater string 10 1! 12 13 · 14 Note: Jewelry 1 147' 1.50' 2 2983' 104.' 3 3016' 3.14' 4 3051' 8.00' 5 3343' 121' 6 3621' 139' 7 3854' 2.50' 8 3887' 3.14' 9 3923' 4.93' 10 4302' 2.50' 11 4337' 3.13' 12 4373' 4.93' 13 4411' 1.30' 14 4414' Offs "X" Nipple Brown "CC* Safety Jt. Offs "XA" Sleeve Offs RDH Dual Pkr. 6 Blast Joints 7 Blast Jonts Brown Safety Jt. 57M ~ Shear~ Otis "XA* Sleeve Offs RH Pkr. 40M ~ Shear Brown Safety Jt. 57M ~ Shear Offs *XA" Sleeve ~ Offs "XN* Np~e ~ T.I.W. Re-entry 2.313" 3.25' 2.31' 3.69" 3.0' 8.38" 2.5' 3.69" 2.5' 3.69' 2.5" 3.75" 2.313' 3.75 3.0' 8.38" 2.5' 3.75 2.313' 8.38' 2.375' 3.5' 2.205' 3.25' 2.375' 3.5' A 139' 1.50' ,~:,,,,,~..,.r~ B 3091' 1.28' ¢~'~' AA 147' 1.20' ~:u,,~, C~sin~ and Tubing Surface 20' Intermediate 13 3/8" Prod. Casing 9 518" Prod. Tubing 2 7/8' (1) Prod. Tubing 2 7/8' (2) Heater String 2 3/8' (3) Offs "X" Nipple Offs *XN" Nipple Offs 'X* Nipple 94# H -40 68~ K-55 43.5~ P- 110,5-95,N-80 6.5~ N-80 6.5~ N*80 4.7~ N-80 2.313' 3.25' 2.205" 3.5' Bult 365' Bult 3202' 8RD/Bult 6376' 8RD 4414' Bult 3O95' 8RD 1584' Collapsed 9-5/8" casing (4621'-4626') worked w/swage & c:~g. roller duflng 1973 completion Perforations A 3255'-3343' 4 Sqz Closed 3362'-3436' 4 6Er String 2 Open B 346~-3582' 4 Sqz Closed C 3624'-3752' 4 61' String 2 Open D 3755'-3894' 4 ~9' ~rlna 2 P~l~k~r aden 3939-4002' 4 Sqz Closed E 404~-~28' 4 81~ String 1 Packer Open 6/92 F 4392'-4778' 4 50' String 1 Closed 6/92 G 4808'-4927' 4 36' StNng 1 Closed 6/92 5/7/91 2.3" GR, XN at 3091' RKB 6/2/93 2.3" GR, XN at 3091' RKB ECEIYED AUG 2 6 1994 Uii & Gas Cons. Commission Anchoraye 2/23/~;K] 1.75" I:X:liler, fill at 4808' RKB 1/1 1/91 1.75" bailer, fill at 47[77 WLM 5/7/91 1.5" bailer-, fill at 4677'RKB 6/20/92 1.75" bailer, fill at 4784' RKB 8/7/93 2" bailer, fill (XA) at 4342' RKB 8/17/94 COILED TUBING BOPE LUBRICATOR BLIND RAMS SHEAR RAMS SLIP RAMS PIPE RAMS .RISER 2-7/8" EUE 8RD TREE CONNECTION Swab Valve Double Master Valves ........... Wellhead AU6 2 6 '1994 Gas Cons. Commissio~ Anchor~.~e AOGCC PACKING SLIP One box contains: BRU 224-3¢-. L/ \~ ~¢f~mal Neutron Decay Log (TDT-P) Tape, Sepia, Blueline Print ~) ~ating Record ~.,"~ Sepia, Blueline Print BRU 232-.26 ~__ e~al NeutrOn Decay Log . ~ Sepia, Blueline Print (TDT-P) Tape, Sepia, Blueline Print ~/~~ ~L Tie-In Log BRU 211-3 ~ ~~ B¢~~ ~mai Neutron Decay Log (TDT-P)~~ape, Sepia, ue ~ne Print ~~/ /~ ~forating Record ~' S~~~l~i~Print Alas,~ Oil & G~ Cons. Com~ssion BRU 212-24 ~al Neutron Decay Log (TDT-P) _cape, bep~a, Blueline Print % "~r Flow Log ~¢ b¢~ Tape, Sepia, ~;;:¢/' ~ (WFL) Blueline Print One copy 'of blueline prints ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 212-25 Beluga River Unit 232-04 Beluga River Unit 233-27 Beluga River Unit 14-19 Beluga River Unit 244-04 Belu~aRi~ 0ni~ .... Beluga River Unit 224-13 Beluga River Unit 212-18 Beluga River Unit 221-23 Beluga River Unit 214-35 Beluga River Unit 232-09 Beluga River Unit 224-23 Beluga River Unit 232-26 Beluga River Unit BRWD-1 Beluga River Unit 211-03 Beluga River Unit 224-34 Beluga River Unit 214-26 Burglin X33-12 Pretty Creek Unit #1 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman jo/rpc~z-energy '~ prin~ed on recycled paper ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Rosanne M Jacobsen, Atty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well reCords and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. w Jo .ston \ Chairman ~ jo/rpc~z-energy ~,.~'~ pri~ted on recycled paper ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that You are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the matedal in these files, please notify the Commission no later than August 8, 1994: Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral headng and, if the latter, the reasons you believe a written submission would be insufficient. Chairman ~ jo/rpc~z-energy ~) i:)rinted on recycled pepet b y C;.~ ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 2767542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy ~10 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open h01e well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the matedal in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a wdtten submission .; _D.av.id VV John n --- · Chairman ~.~ jo/rpclz-energy STATE OF ALASKA ALASKA:OIL AND GAS CONSERVATION COMM'ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well 2000' S & 50' E of the NW Cor., Section 24, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) K.B. 20.7' 6. Lease Designation and Serial No. ADL 21127 7. Permit No. 72-015 8. APl Number 5o-283-20037 9. Unit or Lease Name 10. Well Number BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonrn, ent see 20 AAC 25.105-170). Well BRU 212-24 has been shut-in since 12/15/84. String II was returned to production on 7/8/85 and String I was returned to production 7/11/85. The well was flared for clean-up within the guidelines of Regulation 20 AAC 25.235(b). RECEIVED JUL 1 7 !985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. . / Signed ~ Title Area Engineer The space below for Commission use Conditions of APproval, if any: By Order of Approved by] COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate co~PurmoN am, o~T- as~gDum .... CHEVR'ON U.S.~%. INC. AREA: Beluga River Field PROPERTY: Beluga River Unit WELL NO: BRU 212-24 LAND OFFICE: LEASE NO: API NO: Anchorage ADL-21127 50-283-20037 LOCATION AT SURFACE: 2000' S & 50' E of the NW Corner, Section 24, T13N, R10W, S.M. LOCATION AT TOTAL DEPTH: Straight Hole ELEVATION: 20.7' K.B. TOTAL DEPTH: 6380' EFFECTIVE DEPTH: 4957' CASING:30" Driven to 79' 20" Cemented at 365' 13-3/8" Cemented at 3202' 9-5/8" .Cemented at 6376' SUMMARY PLUGS: DRILLED BY: Brinkerhoff Signal Inc. DATE COMMENCED WORK: 9/20/84 DATE COMPLETED WORK: 11/17/84 Rig #58 DATE: 12/84 t ECEIVED F~ ~ ~ 1985 Alaska Oil & Gas Cons. Comm;$sion Anchorage Beluga River Unit Well · 212-24 Current Perforation Status As Of I 1/15/84 lof4 OtisRDH Dual Setat 3051' on 11/12/84 Top of the Sterling A Zone at 3264' Hole Interval HPF Size Date -h3255-3256' 4 1/2" 10/21/84 ~_3268' 4 1/2" 9/24/73 Gun.Type Schl Csg 4" Hyper 2 GO- Int Csg 3275-3293'4 1/2" 9/29/73 3326-3343'4 1/2" 9/29/73 3362-3414'4 1/2" 9/29/73 4 1/2" 10/23/84 3428-3436'4 1/2" 9/29/73 GO- Int Csg C-O-IntCsg GO- lnt Csg Schl Csg 4" Hyper 2 GO-int Csg Top of the Sterling B Zone at 3449' 3469-3480'4 1/2" 9/29/73 3487-3494' 4 1/2" 9/29/73 3502-3524'4 1/2" 9/29/73 3552-3559'4 1/2" 9/29/73 3572-3582'4 1/2" 9/29/73 GO-IntCsg GO-IntCsg GO- Int Csg GO-IntCsg GO- Int Csg Top of the Sterling C Zone at 3597' 3624-3636' 4 1/2" 9/28/73 4 1/2" 10/23/84 3642-3658' 4 1/2" 9/28/73 3662-3672' 4 1/2" 9/28/73 4 1/2" 10/23/84 3688-3708' 4 1/2" 9/28/73 3692-3708' 4 1/2" 10/23/84 3715-3719' 4 1/2" 9/28/73 3732-3737' 4 1/2" 9/28/73 3742-3752' 4 1/2"-9/28/73 GO-IntCsg Schl Csg 4" GO-IntCsg GO-Int Csg Schl Csg 4" C,O-lntCsg Schl Csg 4" C,O-lntCsg GO-lntCsg GO-IntCsg Hyper 2 Hyper 2 Hyper 2 Under/ Over Balance Over Over Over Over Over Over Over Over Over Over Over Over Status Sq'd Sq'd Resq'd Sq'd Sq'd Open Date 10/21/84 9/25/73 10/18/84 10/18/84 10/18/84 Open RePerrd Open Sq'd 10/17/84 Sq'd 10/17/84 Sq'd 10/17/84 Sq'd 10/17/84 Sq'd 10/17/84 Over Sq'd 10/17/84 Over Open RePerFd Over Sq'd 10/17/84 Over Sq'd 10/17/84 Over Open RePerFd Over Open Over Open RePer£d Over Open Over Open Over Open Beluga River Unit Well s 212-24 Current Perforation Status As Of 11/!§/84 2of4 Top of the Beluga D Zone at 3752' Hole Interval HPF Size Data Gun Type 3755-3757'4 1/2" 9/25/73 GO-IntCsg 3774-3779' 4 1/2" 9/25/73 GO-IntCsg 3792-3507' 4 1/2" 9/28/73 GO-IntCsg 3818-3822', 4 1/2" 9/28/73 GO-lntCsg 3830-3834'- 4 1/2" 9/28/73 GO-IntCsg ~3842-3862' 4 1/2" 9/28/73 GO-lntCsg 3877-3882' 4 1/2" 9/28/73 C,O-IntCsg ~3890-3594' 4 1/2" 9/28/73 GO-IntCsg Under/ Over Balance Over Over Over Over Over Over Over Over OtisRH Packer Setat 39~3' on 11/12/84 3939-3941'4 1/2" 9/28/73 GO-IntCsg -3951-3956'4 1/2" 9/28/73 GO-IntCsg 3965-3969'4 1/2" 9/28/73 GO-lntCsg ~39g4-4002' 4 1/2" 9/28/73 C,O-IntCsg Over Over Over Over Top of the Beluga E Zone at 4023' 4049-4064' 4 1/2" 9/28/73 GO-lntCsg -- 4070-4074: 4 1/2" 9/28/73 GO-IntCsg 4083-4089'4 1/2" 9/25/73 C,O-IntCsg ~4116-4118' 4 1/2" 9/28/73 GO-IntCsg 4139-4143'4 1/2" 9/28/73 C-O-IntCsg '~4148-4152' 4 1/2" 9/28/73 GO-IntCsg 4202-4206' 4 1/2" 9/25/73 GO-IntCsg ~~ 1/2" 9/28/73 GO-IntCsg ~ 1/2" 9/28/73 C,O-IntCsg 4266-4276'4 1/2" 9/28/73 GO-IntCsg 4252-4290'4 1/2" 9/28/73 GO-IntCsg 4321-4328'4 1/2" 9/28/73 GO-lntCsg Over Over Over Over Over Over Over Over Over Over Over over Status Open Open Open Open Open Open Open Open Sq'd Sq'd Sq'd Sq'd Open Open Open Open Open Open Open Open Open Open Open Open 10/16/84 10/16/84 10/16/84 10/16/84 Beluga River Unit Well s 212-24 Current Perforation Status As Of 11/15/84 3of~I Top of the Belug$ F Zone ~ 4345' Otis RH Packer Setat 4373' on 11/12/84 Hole Interval HPF Size Dat~ Gun Type Under/ Over Balance 4392-4400' 4 1/2" 9/25/73 GO-IntCsg 4 1/2" 10/14/84 Schl Csg 4" 4413-4417L, 4 . I/2"9/25/73 GO-lntCsg 4435-4446' 4 1/2" 9/28/73 GO-IntCsg ~4482-4492'~4 1/2" 9/28/73 GO-IntCsg 4 1/2" 10/14/84 SchlCsg4" 4518-4521'4 1/2" 9/25/73 GO-IntCsg .~4523-4530'~ 4 1/2" 9/28/73 GO-lntCsg 4538-4541'4 1/2" 9/28/73 G0-1ntCsg ~-4545-4551~ 4 1/2" 9/28/73 GO-IntCsg 4563-4571'4 1/2" 9/28/73 .GO-lntCsg 4604-4605'~ 4 1/2" 9/20/73 GO-Int 4618-4633'4 1/2" 9/20/73 GO-IntC~g 4679-4697'~ 4 1/2" 9/28/73 GO-IntCsg 4 1/2" 10/14/84 Schl Csg 4" 4714-4720'4. 1/2" 9/28/73 GO-IntCsg 4747-4752~ 4 1/2" 9/28/73 GO-IntCsg 4764-4778'4 1/2" 9/28/73 GO-IntCsg 4 1/2" 10/14/84 Schl Csg 4" Hyper 2 Hyper Z Hyper 2 Hyper 2 Status Date Top of the Beluga G Zone ~t 4778' .-,-~4 112" 9/28/73 GO-lnt ~~-- 112" 9119/73 GO-lntCsg .,~4549-4853w'4 1/2" 9/19/73 GO-IntC~g 4866-4870'4 1/2" 9/19/73 GO-lntCsg /-4578-4883'/4 1/2" 9/19/73 GO-lntCsg 4887-4889'4 1/2" 9/19/73 GO-IntCsg .,~4907-4911' 4 1/2" 9/19/73 C,O-lntCsg 4922-4927' 4 1/2"'9/19/73 GO-lnt~g Over Sq'd 10/13/84 Over Open RePerrd Over Sq'd 10/13/84 Over Sq'd 10/13/84 Over Sq'd 10/13/$4 Over Open RePerf'd over Sq'd 10/13/84 Over Sq'd 10/13/84 Over Sq'd 10/13/84 over Sq'd 10/13/84 Over Sq'd 10/13/84 over Sq'd 10/13/84 over Sq'd 10/13/84 Over Sq'd 10/13/84 over Open RePert'd Over Sq'd 10/13/84 Over Sq'd 10/13/$4 Over Sq'd 10/13/84 Over Open RePert"d EZSV Cement Retainer Set at 4967' on 10/12/84 Over Over Over Over Over Over Over Over Open Open Open Open Open Open Open Open Beluga River Unit Well ~ 212-24 Current Perforation Status As Of 11/15/84 4of4 Hole Interval HPF Size Date Stams Dsie Gun Type Under/ Over 5032-5036' 4 1/2" 9/28/73 GO-IntCsg 5049-5052'- 4 1/2" 9/28/73 GO-Iht Csg 5068-5072'- 4 1/2" 9/25/73 GO-IntCsg 5090-5102", 4 1/2" 9/28/73 GO-lntCsg ../5112-5115~ 4 I/2" 9/28/73 GO-IntCsg "L~I17-5126Y 4 1/2" 9/28/73 GO-IntCsg Ove£ Over Over Over Over Over ~op of the Beluga H Zone at 5161' 5162-5196' 4 1/2" 9/26/73 C-O-IntCsg 5220-5228', 4 1/2" 9/26/73 GO-lntCsg ~5232-5235~ 4 1/2" 9/26/73 GO-IntCsg ~-5237-52,10:~ 4 1/2" 9/26/73 GO-Int Csg ~5_26_7-5_270' 4 1/2" 9/26/73 GO-lntCsg 5292-5296'4 1/2" 9/26/73 GO-IntCsg Over Over Over Over Over Over EZSV Cement Retainer Setat 5310' on 10/12/84 /7334-5345~ 4 '~5358-5366:/4 5380-5400' 4 /~_~154.14-542T, 4~ 5455:5459~ 4 ~5573-5582' 4 5648-5658'- 4 5663-5672' 4 5681-5684'- 4 57~-5714' ~ 1/2" 9/26/73 GO-IntCsg 1/2" 9/26/73 GO-Iht Csg 1/2" 9/26/73 GO-lntCsg 1/2" 9/26/73 GO-IntCsg 1/2" 9/26/73 GO-lntCsg 1/2" 9/26/73 GO-lntCsg 1/2" 9/26/73 GO-IntCsg 1/2" 9/26/73 GO-IntCsg 1/2" 9/26/73 GO-IntCsg 1/2" 9/26/73 GO-IntCsg Ove£ Over Over Over Over Over Over Over Over Over Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd Sq'd 10/12/$4 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 10/12/$4 10/12/84 10/12/84 10/12/84 10/12/S4 10/12/84 10/12/84 10/12/84 10/12/84 10/12/84 Top of the Beluga I Zone at 5764' 5766-578(}:~- 4 1/2" /5798-5818'. 4 1/2" 5822-5830~ 4 1/2" /5913-5919' 4 1/2" 5999-6022'4 1/2" /-6283-6297' 4 1/2" 9/18/73 GO-IntCsg 9/18/73 GO-lntCsg 9/26/73 GO-IntCsg 9/26/73 GO-lntCsg 9/16/73 GO-lntCsg 9/16/73 GO-IntCsg Over Over Over Over Over Over Sq'd Sq'd Sq'd Sq'd Pluged Pluged 10/12/84 10/12/84 10/12/$4 10/12/84 9/26/73 9/26/73 Page I ~ ~, BRU 212-24 9/17-9/19/84 MOving rig from BRU 224-13 to BRU 212-24 and rigging up. 9/20-9/21/84- COmpleted rigging up. Accepted rig at 8:00 p.m. 9/20/84. Built 3% KCL- saturated Nail brine completion fluid to 9.9 ppg. Rigged up. Flanged up kill line to (string 1) with returns through 2-7/8" tubing (string 2), 2-3/8" tubing (string 3), 2- 1/16" tubing (string 4) and the 9-5/8" annulus. 9/22-9/23/84 9.9 ppg Killed well by bullheading 20 bbls down string 1 out open XA sleeve at 4170', opened XA sleeve at 3914', pump 41 bbls down string 1 with returns up string 2. Closed the XA sleeve at 3914', open the XA sleeve at 3531', pump 18 bbls down string 1 with returns up string 3. Close XA sleeve at 3531', open XA sleeve at 3198', pump 173 bbls down string I and up the tubing X 9-5/8" annulus. Set plugs in "S" nipples at 90' in string 1, 86' in string 2 and 114' in string 3. Removed tree. 9/24/84 9.9 ppg Nippled up BOPE and tested to 3000 psi. Pulled plugs from "S" nipples in string 1, 2 and 3. Pulled 68 jts 2-1/16" tubing. Changed rams to 2-3/8". Release "J" latch on 2-3/8" tubing (string 3). Recovered 103 jts of 2-3/8" tubing. Changed rams to 2- 7/8". Released string 2 at CC jt built into triple packer at 3243'. Recovered 101 its of 2-7/8" (string 2) tubing. Released string 1 at CC jt at 3232'. Recovered 102 its of 2-7/8" tubing (string 1). Picked up drill pipe and RIH Tristate fishing tools and with CC jt retrieving tool. 9/25/84 9.9 ppg Engaged fish at 3224'. Jarred and pulled 90,000# over pull to POOH. Recovered triple packer, dual packer and all tubing to string I straight pull safety jt at 3895'. RIH with overshot engaged fish at 3892'. Pulled 70,000# overpull. 9/26/84 9.9 ppg POOH with ~ safety jt (bottom half), 2 pup its, XA sleeve, packer, "S" nipple, 2 pup its, 6 its 2-7/8" tubing, pup it, Camco Mandrel, pup jr, i jt 2-7/8" tubing, ~ safety jt (top half). RIH with overshop dressed with a 3-5/8" grapple. Latched fish at 4159'. Worked fish free with 100,000# overpull. Pulled up hole 13 strands and swabbed well in attempt to circulate out kick. Could not circulate past packer. Killing well by bullheading down the annulus. 9/27/84 9.9 ppg stabili+.ed well. RIH to 3257'. Circulated 9.9 ppg brine. POOH slowly, filling hole at every 3 stands. Recovered bottom half Brown safety it, 1 2-7/8" tubing pup, Otis XA sleeve, XO, Brown Hi-RSP packer, XO,~ Otis position 2 "S" nipple, 11 its 2- 7/8" tubing, Camco MMA Mandrel, I 2-7/8" jt and top half Brown safety jt top of fish at 4568'. RIH and engaged fish with overshot with 3-5/8" grapple. Could not move fish with 135,000# overpull. Disengaged fish. Circulated bottoms up. 9/28/84 9.9 ppg RIH with washover shot and clean out fill from 4567'-4584'. Spotted two high vis X-C polymer pills. POOH, washover basket had ~ cup metal (probably packer shear pieces) and two cups white chalk and sand. RIH with Tristate overshot with 3-5/8" packoff grapple. Tagged top of fish at 4568'. Jarred fish with 100,000# overpull with no movement. Released fish. POOH. RIH with washover shoe to 643'. Had additional flow back up drill pipe. Circulated bottoms up at 500 psi backpressure. Had 9.9 ppg in and 8.7 ppg fluid out. Hole fluid turbulent with very slow rise. Bullheaded 100 bbls down drill pipe. Had 910 psi casing pressure. Bled off pressure. Hole fluid turbulent. Slow drop in fluid level. Added 6 bbls of fluid in 7 Page 2 BRU 212-24 hours. Hole fluid almost calm. Removed safety valve, installed inside BOPE. RIH slowly while monitoring fluid level and flow back. 9/29/84 9.9 ppg RIH With washover tool to top of fish at 4568'. Circulated bottoms up. Washed over to packer fish at 4584'. POOH. RIH with 7-5/8" overshot with 3-5/8" grapple to 4568' and engaged fish. Could not pull or jar fish loose. Ran 1~" sand pump on wireline down the dp to 4697'. Bailer full of fine sand. Re-ran sand pump - stopped at 4700'. Recovered fine sand' 9/30/84 9.9 ppg ~ fr~epoint below packer fish at 4584'. Torque readings showed fish free but could not get freepoint tool past 4691'. RIH with 7-5/8" overshot with 3-5/8" grapple. Engaged fish at 4568'. RIH with 2-1/8" O.D. 2-7/8" tubing jet cutter. Could not get past 4628' with 30,000# pull and 500 psi on drill pipe. Shot tubing at '4621'. POOH with wireline. POOH with overshot. Recovered bottom half of safety it, pup jt, XA sleeve, packer, "S" nipple, 3 pup its, 17' 2-7/8" tubing. Top of fish at 4621'. 10/1/84 RIH with 8-1/8" washpipe - worked over fish at 4621'. 4650'. POOH. RIH with 7" washpipe. 9.9 ppg Had to rotate from 4623'- 10/2/84 9.9 ppg Circuit{ted bottoms up at 4589'. Dressed top of fish at 4621'. With hollow mill, washed over 2-7/8" tubing fish 4621'-5122'. Rotated from 5122'-5152' and washed over 5152'-5167'. Pumped a 25 bbl XC polymer 130 see. vis sweep. Circulated bottoms up. Had some salt and a small amount of sand in returns. POOH. RIH with outside 2-7/8" tubing cutter. Circulated bottoms up at 5172'. Cut 2-7/8" tubing fish at 5168'. Recovered 17~ its 2-7/8" tubing (sand filled and under pressure) (note: also recovered CEV plug lost in hole 12/29/80), RIH with wash pipe and washed over top of fish at 5168'. 10/3/84 9.9 ppg Cleaned out fill from 5168' to top of packer at 5307'. POOH with washpipe. Tested BOPE to 3000 psi. RIH with overshot. Engaged fish at 5168'. Jarred up to 75,000# and pulled to 100,000# without success. Disengaged overshot and circulated bottoms up. RIH with lt" O.D. sinker bar inside fish. Reached 5244'. POOH. Ran freepoint - fish free at 4217'. Recovered 3~ its 2-7/8" tbg, MMA Mandrel, XA sleeve. 10/4/84 9.9 ppg Rill with mill to 5308'. Circulated bottoms up. Milled 12" on Armco 3t" seal-lok box which is a part of the Baker model D seal assembly. RIH with milling assembly #2. Circulated. Milled approximately 2' and packer moved down hole. Chased pack to 5337'. Fluid level dropped. Took approximately 7 bbls to fill hole. Circulated bottoms up. Pulled up to 3200' and circulated bottoms up. Had a small amount of gas cut mud. 10/5/84 10.0 ppg POOH with mill. RIH with overshot to 5335'. Engaged packer fish. POOH - had drag to surface. Recovered remains of model D packer and seal assembly, 2 X-O, 1 "D" nipple with plug in nipple and 19 its 2-7/8" tubing. RIH with bit and scraper. Tagged fill at 5911'. Cleaned out to 5945'. Circulated and conditioned hole for logs. Pa~e 3 B~U 212-24 10/6-10/7/84 10.1 ppg ~ CET~ CNL and CBL from 5946'-2800'. RIH open ended to 5945' - no fill. RIH with Halliburton Champs packer to test 5334'-5919' -set packer at 5315'. With tail at 5328', opened tool at 12:53 pm (10/6/84). See attached. Closed tool at 11:03 pm 10/6/84 for final S.I. Recovered packer at 5315' at 3:16 am 10/7/84 for 4 hrs 13 mins S.I. POOH with test tools. Set retrievable bridge plug at 5315'. RIH with packer to 4975' and set packer at 8:24 pm 10/7/84. Opened tool at 8:27 pm 10/7/84. Had Cushion to surface in 48 rains and dry gas in 1 hr 27 rains at 870 psi. !.0/8/84-10/9/84 10 ppg Shut well in at 10:54 am 10/8/84. Pulled packer loose at 1:20 pm for a 2 hr 26 min S.I. Circulated out extremely gas cut 8.6 ppg. mud. POOH with test tools. Recovered bridge plug at 5315'. !..~/!0/8_4 9.9 ppg Tested choke, choke and kill lines, pipe rams, blind rams, super choke, HCR to 3000 psi and annular to 1500 psi. Set bridge plug at 4975'. 10/11/84 9.9 ppg RIH w'iih packer with 2000' of fresh water cushion. Set packer at 4352'. Opened tool at 1:42 pm. Had strong blow to surface immediately and rapid drop of annulus fluid. (Volume to fill annulus equal to empty DP volume.) Pumped down DP - sheared reversing sub with 2400 psi pump pressure. Circulated 9.9 ppg mud. Recovered bridge plug from 4975'. See attached. RIH with Halliburton EZSV emt. retainer. Circ. Set retainer //1 at 5310' for squeeze #1 of perfs 5334'-5345'. Pull out stab-in tool. Cire 1] b/u. Test lines to 2000 psi. Stab into retainer, establish injection rate with 1400 psi at 1/3 BPM. 5 rain shut in press = 1200 psi. Pullout of retainer with 300 psi backpressure on annulus. Halliburton pumped: 10 bbls fresh water, 200 sx (230 cf) "G" neat emt. 15.8 ppg, 5 bbls fresh water, displaced with 22 bbls mud. Stab into retainer with 500 psi on annulus. Squeezed 150 sx cmt'(173 cf) below retainer from 1800 psi/3/4 BPM to 2200 psi/i+ BPM, ISIP = 2200 psi bled to 1350 psi in 5 min and held. P/U 10' and rev circ 2x dp volume, including 50 sx (58 cf) emt. POH. RIH with 8~" bit and 9-5/8" esg scraper to 5000'. Circ B/U. POH. RIH with second EZSV retainer. Circ and set retainer at 4967' to squeeze perfs 4032'-5036'. Pull out and tire B/U. Stab into retainer with 500 psi on annulus, establish injection rate with 1750 psi at 3/4 BPM, 5 min SIP - 1400 psi. Pull out of retainer. With 300 psi baekpressure on annulus, pumped: 10 bbls freshwater, 150 sx (173 cf) "G" neat cmt 15.8 ppg, 5 bbls freshwater, and displaced with 28 bbls mud. Stab into retainer with 500 psi on annulus, squeezed 127 sx (146 df) cmt through retainer from 1300 psi/ 3/4 BPM to 2050 psi/ ¼+ BPM, ISIP - 2050 psi. Bled to 2000 psi in 5 min and held. Picked up 10', rev circ hole volume, including 23 sx (27 cf) cmt. 10/13/84 RIH-wi[h third EZSV cmt retainer. Cire set retainer at 4345'. Cire 2BU. Test lines to 2500 psi. Stab into retainer with 500 psi on annulus, establish injection with 1500 psi/ i BPM, 5 min SIP = 1500 psi. Pullout of retainer. With 300 psi backpressure on annulus, pumped: 10 bbls fresh water, 150 sx (173 cf) "G" neat emt 15.89 ppg; 5 bbls fresh water; and displaced with 15 bbls mud. Stab into retainer. With 500 psi on annulus, pumped all cmt through retainer and over-displaced peres at 4392'-4400' with 5 bbls fresh water. From 900 psi/ 3/4 BPM to 1500 psi/ ¼+ BPM, ISIP = 1550 psi 5 min sip = 1500 psi pullout of retainer. Rev tire and WOC 10 hfs (for 500 psi compressive strength). Stab into retainer. Could not establish injection rate with 2000 psi on 3 attempts (bled back slowly to 1500 psi; pump in 1 t bbls, got only ¼ bbl back). POH with stab-in tool. M/II 8~" bit and junk sub. RIH tag cmt retainer at 4340'. Drill on retainer 4340'-4343', pushed remainder to 4381'. Pa~e 4 BRU 212-24 10/14-10/15/84 Drilled oUt firm emt 4381'-4754'. RIH to 4825'. Cite BU. POH LD junk sub and PU 9-5/8" cs~ scraper. RIH to 4400'. Cite BU. POH RU Schlumberger Wireline. Made four perforating runs USING Schlumberger's 4" HyperJet II easing gun, shooting 41" OD holes per foot. //1 4764'-4778', 14', no misfires. #2 4679'-4697', 28', no misfires #3 4482'-4492', 10', no misfires 4392'-4400', 8', all misfired #4 4392'-4400', 8', 4 shots misfired M/LL Halliburton test tools. Test surface lines to 1500 psi. Set Champs packer at 4342', to test perf'd intervals; 4392'-4400', 4482'-4492', with tail at 4355', 4679'- 4697', and 4764'-4778' (also, original perf'd intervals to cmt retainer at 4967'). Open tool 2:15 pm 10/14/84. With full annulus had strong blow. 2000' fresh water cushion to surface in 3 mins; gas to surface in 10 min. Shut in to repair production test separator choke (4~ hrs), ISIP = 1090 psi. Pressure stabilized at 1480 psi in 2~ hrs. Open flow to separator choke with ~" inserts at 8:20 pm 10/14/84. See attached. 10/16/84 Completed production test. Closed tool at 7:00 am for 2 hr buildup. Bled off DP pressure. Pump down DP sheared out reversing sub. Circ B/U. Pull packer. Cire 3 hole volumes. POH slow with test tools. R/U Schlumberger. Set EZSV bridgeplug at 4105'. R/D Wireline. M/U EZSV cmt retainer on DP. RIH. Cite and set retainer at 3904'. Circ B/U. Test surface lines to 2500 psi. With 500 psi on annulus est. breakdown 850 psi/ ~+ BPM, 5 min sip - 700 psi. Pullout of retainer. With 300 psi backpressure on annulus, Halliburton pumped: 10 bbls fresh water; 150 sx (173 cf) "G" neat cmt at 15.8 ppg; 5 bbls freshwater; and displaced with 15 bbls mud. Stab into retainer. With 500 psi on annulus, squeezed 122 sx (140 cf) emt through retainer from 450 psi/ 2/3 BPM to 1350 psi/ ¼+ BPM: ISIP -- 1350 psi, bled to 1200 psi in 5 min and held. Start mix 1:35 am. CIP 2:58 am 10/16/84. P/U 10' rev circ 1 hole volume including 28 sx (33 cf) cmt. 10/17/84 Test BOPE. Test BOP, choke, choke and kill lines to 3000 psi. Replaced a kill line valve and annular preventers to 1500 psi. Rigged up Schlumberger. Wireline set EZSV retainer at 3605'. POH. Rigged down Schlumberger. RIH with EZSV retainer and set at 3535'. Pulled out of retainer and tire and condition mud. Stabbed into retainer. Establish breakdown of 1350 psi for ~ bbl./min; 1420 psi for I bbl/min and 1500 psi for 2 bbl/min. Put approx. 800 psi on annulus. Pump 5 bbl water follwed by 150 sx (30.7 bbl) cmt followed by 5 bbl water and displaced with 46~ bbls mud. Start mix cmt at 2:55 pm with CIP at 4:12 pm. Slurry weight 15.6- 16.0 ppg. Press increased from 900 psi when cmt reached perfs to 1870 psi at conclusion of displacement. Pulled out of retainer. Reversed out a trace of cmt. Chain out of hole. RIH with bit to 3500'. No fill or cmt to this depth. Circ bottoms up. POH. Make up EZSV retainer on dp. RIH with retainer and set at 3452'. Stabbed into retainer. Established breakdown of ¼ bbl/min at 1500 psi; ~ B/m at 1575 psi; 1 B/m at 1650 psi and 2 B/m at 1740 psi. Put 1150 psi on annulus. Pumped 5 bbl water followed by 100 sx (20 bbl) Class "G" cmt, followed by 5 bbl water and displaced with 45 bbl mud. Start mix cmt at 3:15 am with CIP at 4:33 am. Final squeeze press of 1930 psi. Reversed out approx 2 bbls cmt. 10/18/84 Run and wireline set EZSV at 3350'. RIH to 3239' (center of retainer rubbers). Circ bottoms up. Hook up cmt lines and test to 2500 psi. Set EZSV retainer at Page 5 BRU 212-24 3239'. Establish breakdown at ~ B/m at 1650 psi and pump rates of 1 B/m at 1720 psi and 2 B/m at 1820 psi. Pump 5 bbls H20 and displaced with 42 bbls mud. Start mixing cmt at 12:09 pm with CIP at 1:25 pm. Final squeeze press 1700 psi. Slurry weight 15.6-16.1 ppg. WOC until 1:30 am. RIH with bit. Found top cmt at 3228'. Drilled firm cmt 3228'-3238' (top retainer). Drld retainer 3238' to 3241'. 10/19/84 ~ drilling on firm cmt from 3313' to 3340'. Fell through to retainer at 3348'. Drlg retainer 3348'-3351'. Clean out to 3443'. Drl on junk to 3449'. POH for bit change. RIH. Drl on junk 3449' to 3451' and retainer 3451' to 3454'. Drl cmt 3454'-3533' and retainer 3533'-3536'. Drl cmt 3536' to 3602'. Drlg on junk at 3602'. POH for bit change. Clean boot basket. 10/20/84 Drilled retainer at 3602'. Drld cmt 3603'-3616'. Drld on junk 3616'-18' and cmt 3618'-80'. Slip in hole to 3899,. Drld junk and cmt 3899' to top of retainer at 3904. Drld retainer 3904'-07' and cmt to 3940'. POH. Clean boot basket and RIH. Cut drilling line. RIH. Drld junk and cmt 3940' to 4003' and cmt to 4040'. Slipped on to 4101', top of retainer. Drld 15 + rain and retainer slid to 4786'. Circ and condition mud. POH. 10/21/84 RIH-t0-4786'. Drilled on junk. Bottom fell out. Slipped to 4961'. Bottom firm at 4961'. POH. PU scraper and RIH to 4961'. Circ and condition mud for logs. POH. Rig up Schlumberger. RIH and ran CET/GR/CCL from 4961' to 3100'. POH. Rig up EZSV retainer bp. RIH and set at 3310'. POH. PU 4" HyperJet II casing guns and shut four ~" jet holes at 3255'-56'. POH. Rig down. Make up RTTS squeeze pkr. RIH to 3175' and set pkr. Test lines to 2500 psi. Establish injection rate of ~ B/m at 700 psi; 1 B/D at 850 psi and 2 B/min at 1330 psi. Pump 5 bbls H20 followed by 32 bbls (150 ax) Class "G" cement followed by 5 bbls H20 and displaced with 46 bbls mud. Mixed cement. Slurry weight 15.7-16.1 ppg. Final squeeze rate ½ B/min at 1500 psi. SI final pressure 1430 Psi. 10/22/84 POH with squeeze pkr after 7 hrs wait. Tag cmt at 3253'. Drilled out soft cmt to 3262'. Wait an additional 3 hrs. Braden head test perfs 3255'-56' to 2100 psi one gauge and 1830 psi another gauge for 15 minutes. No bleed off. Drill cmt to top retainer at 3300'. Drill on retainer 3300' to 3303'. Push, slide and drilled to 3683'. POH. Set EZSV retainer at 3920'. POH. Perforated with 4" HyperJet II four t" jet holes per foot 3'708*-3692'; 3672*-3662'; 3636'-3624' and 3414'-3362'. RIH to Halliburton Champs pkr at 3189'. Fill 14 Stds (21 bbls) 1489' with water for cushion. Set pkr at 3189' with tail to 3204' for production tests of perforation between 3362' and 3894'. Open tool at 3:13 am. Cushion to surface in 6 min. Gas (wet) to surface in 39 min. 10/24/84 Closed tool at 1840 hfs for 4 hr buildup pressure. Bled off DP press. Fill DP with mud and shearout reverse cite sub at 3155' with 2800 psi. Rev circ twice DP volume through choke. Pull RTTS pkr at 2310 hfs and fill annulus with 8 bbl mud. Circ 1~ X B/U through choke with gaseut mud. Circ additional B/U with annular open and cond mud. PoH (chainout) slow. M/U RR bit #6 and junk sub. RIH to EZSV bridgeplug at 3920'. Drill 1' of BP had some gascut mud rtns. See attached. 10/25/84 Circ out gascut mud throUgh choke. Drilled out EZSV retainer at 3920* and pushed remainder to bottom at 4957*. Tested BOPE: choke manifold, superchoke, choke Page 8 BRU 212-24 pressuring up string 1 - sheared ball at 2700 psi. Rigged up to string 2. Tested surface lines to 3500 psi - could not pressure above 1000 psi. Pumped 8 bbls diesel - annulus showed same pressure. Ran 2.25" gauge ring to shear sub at 3089' - could not set Otis packer at 3051'. Placed plug in XN nipple at 3088' twice - could not set packer. 11/14/84 Set PX-plug in X nipple at 157' in string 2. Pressured to 1000 psi with no leakoff. Retrieved PX plug. Decide to pull string 2 and check catch in assembly. Set PXN plug in XN nipple at 4411'. Opened XA sleeve at 3887'. Changed over hole fluid from diesel to saturated Nacl 3% Kcl brinewater - well dead. 11/15/84 Nippied down X-mas tree. Nippled up Class flI BOPE and tested to 3000 psi. Unland string 2 with 27,000# up wt L/D pup jts, P/U single jt and spaceout. Latched Otis Collet in Otis dual RDH packer at 3050' (35,000# upcut to unlatch). Removed 2.10' pup, added 5.10' pup it. Latched in and set 11,000# of compression on packer (pulled 35,000# to unlatch and check). Pumped down string 2 could tire freely. Rev tire 3 bbls. Still could circ freely down string 2. Ran PXN plug into XN nipple at 3088' in string 2. POH (did not latch plug, had wood chips in keys). Rerun plug - could not latch nipple. POH. Drop N-test tool (2.31" OD) down string 2 followed with 1-3/4" blind box and sinker bars to XN nipple in string 2. Tested lines 2000 psi. Press up string 2 to 2000 psi (packer should set 900-1200 psi) 5 rains. RemoVed BPV from heater string. Tested lines to 3000 psi. Press down annulus to test packer - could cir up string 2. Retested surface lines to 4000 psi. Press string 2 with 3/4 bbl to 3500 psi held solid 5 min. Installed 2-way check in string 1. Tested packer, annulus, and collet seals 2000 psi/30 min with no leakoff. 11/16/84 Removed N-test tool from 3088' in string 2. Installed BPV's in all three strings. Nippled down BOPE. Nippled up and tested X-mas tree to 3000 psi. Removed BPV's. Changed hole fluid from brinewater to diesel. Pumped down string 2 and up string 1 through XA sleeve at 3887'. Closed XA sleeve at 3887'. Opened XA sleeve at 3016'. Pumped down annulus and up string 1 through XA sleeve at 3016'. Began unloading string 2 at 4:45 pm. Began flaring at 6:40 pm. Made +174 bbls. of diesel. Began unloading annulus at 5:30 pm. 11/17-11/18-84 Completed unloading annulus of diesel with string 2 connected to annulus and flowing up open XA sleeve at 3016' in string 1. (Recovered 177 bbls.) Bled annulus pressure to 0 and shut in for two hours. Pressure remained at 0 psi. Put 500 psi back on annulus and shut in. Closed XA sleeve at 3016'. Removed PXN plug from XN nipple at 4410'. Opened string 1 at 4:55 pm - well dead at 5:30 pm. Opened XA sleeve at 3887'. Began unloading long string at 7:50 pm. Well stopped flowing at 8:30 pm. Well began flowing at 10:30 pm. Closed XA sleeve at 3887'. Unloaded diesel from string 1 and rathole 4375'-4957'. Recovered 67 bbls fluid. Opened string 2 to flare (no fluid). Shut in. Installed BPV's in all three strings of tubing. Secured well. Released rig 12..00 noon 11/17/84. Began rigging down Brinkerhoff Rig #58. .5 3'-T5 Z-~Is'' -] ~SL~5"F "3'T5 ZD.~O I Z.S55.¢5' .o. . %.00 ~%%.o~' 1.10 ?..50' qs. oo' 1/---¢5_ lqb.¥q' I 5Ol5.q5' ::%51.54' "3bzI .Oci ' 5-7¥0,33 ! a%oz.gt T~.N. .-70 31.55' l,B0' / q&7~. I -5? - LchN~ 5'r~dCT %,o6 I 2.50' $c~51.5,.-.l ,, 30c~5.OS' ~-/ TTs Z~/~'' ~.-~' %~ ~-~ /,rio BRU212-24 PRODUCrlON TEST WORK OVER 10-11/84 Production Test #1 10/7/84 Perfs 5334'-5919' Beluga H-I Rem_*_rks Tubing Press. Blip ~ 5320' Rate Mcfd Hydrostatic .... 2710 Tool Open .... 931 8/64" choke 825 1216-1384 12/64" choke 700 1204-1309 16/64" choke 590 1243-1337 Build-up ..... 2515 398-650 1000-850 1246-900. Produced 16.7 BBIs of water over 7.5 hour test. Fluid appears to be work over brine. Flowing bottom hole pressure throughout the test was not steady and appeared to be cleaning up or lifting fluid. Production Test ~2 10/8/84 Perfs 5032'-5296' Beluga, G-H Ren~rks Tubing Press. BHP a 4988' R~e Mcfd Hydrostatic 2597 ..... Tool Open ..... 1365 ..... Max. 8/64" choke 1140 1856 937 Max. 12/64" choke 1160 1807 1460 Max. 16/64" choke 1130 1725 1960 Max. 20/64" choke 1190 1604 3292 Build up ..... 2323 ..... Produced 47.8 BBIs. or water over 12.5 hour test. Fluid &ppears to be work over brine. Pressure recorder on the bottom of the bridge plug set a~ 4975' showed that the bridge plug was leaking or the cement bond was poor. Cement bond is believed to be poor. Production Test*3 10/11/84 Perfs 4392'-4927' BelugaF-G Bad test--annulus communica~d with the test zone because of poor cement bond. Production Test #4 10/15/84 Perfs 4392'-4927' Beluga F-G Remarks Tubing Press. BHP · 4347' Rate Mcfd Hydrostatic ..... 2208" ..... Tool Open ..... 940 ...... biax. 8/64" choke 1450 1631- 922 Max. 12/64" choke 1390 1675 1801 Max. 16/64" choke 1190 1613 9140 Build up ..... 1810 ..... Produced 23.3 BBLS of water over 10 hour test. Fluid appears to be work over brine. BRU212-24 PRODUCI'ION TI~T WORK OVER 10-11/84 Production test '5 v/Sterling B squeezed off. 10/23/~4 Perfs 3362'-3594' Beluga D end Sterling A end C Rem~ks Tub~ P~. BHP ~ 3200' R~ Mcfd ~ Hydm~c ------- Ch~ unm~le~> ..... M~. ~/~4" choke 1050 ~ ........................... 206 M~. 12/64" choke 1280 508 M~. 16/64" choke 1280 1178 M~. 20/~4" choke 1260 2118 M~. 24/64" choke 12~ 31~ M~. 28/~4" choke 1260 4191 M~. 32/64" choke 11~ 5552 Bund up ..... - .... Produced 14.2 BBLS of weber over 14.5 hour test. Produced wster believed to be-work over brine. Production Test ~6 10/26/84 Perfs 3624'-3894' Beluga D end Sterling C ., Remarks Tubing Press. BHP ~ 3614' Ra~e MCfd Hydrostatic ..... 1907 Tool open ..... 1311 Max. 12/64' choke 1140 1472 Max. 16/64" choke 1170 1460 Shut In ..... 1475 ' Max. 16/64" choke 1200 1450 Max. 20/64" choke 1170 1435 Max. 24/64" choke 1220 1429 Max. 28/64" choke 1190 1416 Build up ..... 1522 4O0 844 1158 3112 3275 4424 Produced 13.2 BBLS ofwa~r over a 14 hour test. Last hours sample h~d 175000PPM Clorides--same as workover fluid. BRU212-24 PRODUCTION TEST WORK OVER 10-11/84 Final Production TeSt ~ter running tubing. Production Test Short String (String 2) 11/15/$4 Perfs 3362'-38°A' 59' of Beluga D, 59' of Sterling C, 52' of Sterling A Remarks Tubing Press. Ra~ Mcfd Max. 16/64" choke Max. 20/64" choke Max. 24/64" choke 1300 1800 1290 2100 1340 3400 Produced 8.5 BBLS of water over 12 hour test. Water Believed to be work over brine. Production Test Long String (String 1) 11/16/$4 Perfs 4392'-4927' 36' of BslugaG and 50' of Beluga F Remarks Tubing Press. Max. 24/64" choke 1560 Produced 1 BBL of brine work over fluid the last hour of test. Rats Mc£d 4100 CHEVRON U.S.A. J. C. TRANSMITT,\? 4D ACKNOtCLEDCEMENT OF RECEIPT , HATER~AL - (ALASKA) DATE THE FOLLOW/lNG IS A LIST OF MATERIAL ENCLOSED EEREIN. FD- Folded - Rolled S - Sepia - Film X - Xerox pL~~~E CH B - Blue~:i.ne ECK AND ADVISE II~HEDIATELY. P-~ Fo.,Ami RECEIVED 8Y Alaska. Oil & Gas Cons. P. nrqmJss|on /tnchorage NEMJJ~KS ON OTHER SIDE. THIS SH~T BY ~ON U. SJ[. ]~C. BOX 7~9 ii~uq.u'q~Af21~ &l A~A ~C1~ KEYPUNCH INSTRUCTIONS: DUPLICATE COL. 1-11 ON ALL CARDS. PUNCH CARD TYPE ~|RCLE~ IN COL. 13.14, FOR NARRATIVE ACCOUNTS: PUNCH NARRATIVE IN COL. 15.80; USE AS MANY CARDS AS RE- QUIRED AND REPEAT CARD TYPE ON ALLCAR'DS. REPORT OF FIRE G0-106 DO NOT USE THIS SPACE I[COMPANY CODE -T" , 3 4 SEQUENCE CODE ]~ UPDATE CODE ,.. COMPANY 15 P, hev~on U.S.A. DEPARTMENT Producing DATE OF FIRE 12 / 15 ,9 84 7-8 9.10 5-6 BRU 212-24 PLANT/STAT I ON FAC I L I TY I N¥0LYED Q LOCATION (ADDRESS. CITY. STATE) Beluga .River Unit '5 Q DIVISION/AREA AlaSka 15 Q STRUCTURE/EQUIPMENT INVOLVED Heater ~u/!ding 15.65 IF MOTOR VEHICLE. OPERATOR'S NAME 66~80 Q PRODUCT INVOLVED/FLASH POINT(APPROX.) 45 WHAT WAS DAMAGED OR DESTROYED? Hes. ter buildin_~.'. ICL on _~as heater. _~u/col De-MydrAter and fuel gas eysteme~ e!ect~ me EST. LOSS: COMPANY STRUCTURES/EQUIPMENT $200,000 PRODUCT $ NON.COIYPNqY $ 15 25 35 NUMBER OF INJURIES/FATALITIES(EXPLAIN IN ITEM T'r'r) COMPANY EMPLOYEES: NUtVlBER OF LOST WORKDAY INJURIES ~o~e FATALITIES NON.COMPANY PERSONS: NUMBER OF INJURIES ~one FATALITIES HOW DID THE FIRE HAPPEN? (GIVE A FULL NARRATIVE ACCOUNT OF EVENTS LEADING UP TO THE FIRE, HOW IT STARTED, AND HOW IT WAS CONTROLLED AND EXTINGUISHED). Gas production from well was being flared to clean well prior to putting gas to sales line. Operator had checked well at 12:50 am. 'when he returned at 6:50 am the heater building was engulfed in flames. He closed well valves and sales gas line valves then notified his supervisor. Chevron supervisors arrived at well by' 9:15 am. The flame was confined to the piping end of the gas heater. Cas pressure trapped in lines was feeding fire. T"~.e pressure was bled do~,m and f!a,me allo:,'ed to die out. T~. ~ FIRE CONTROL ~ COMPANY CONTROL OR F'-] OUTSIDE HELP USED v !5 TIME FIRE DISCOVERED ~' 3© (l~ CONTROLLED 42.45 46.47 48.51 52.53 Q EQUIPMENT USED BY EMPLOYEES: PORTABLE EXTINGUISHERS: i,~OT ]:~ DRY CHEMICAL - NO. USED 15.17 OTHER - NO. USED SPECIFY 29.31 18.28 LARGE EQUIPMENT: (COMPANY OWNED) ]'--1 MOTOR FIRE APPARATUS )--'IFONVI-EQUIPMENT 41 42 MON I TORS-NO. USED OTHER 44.46 WAS FIRE COMMUNICATED TO OTHER PROPERTY? 7~0 15.17 17.41 NAME OF OROANI ZATION EXTINGUISHED 10: ~0(~ 54. 57 58. 59 HOSE LINES: 3/4", 1" - NO. USED ];CT .... '.r,",' ~ ' .,..~ . ,L; _.... L." ~--' 32. 34 1-1/2" 2-1/2" - NO, USED - NO. USED 35.37 38.40 F-l SPRAY SYSTEM 43 SPECI FY 47. 56 DESCRIBE: 18 (nvFn~ OEC 2 7 Anchorage c,o. ~ o~ ~CD-9-~4) PRINTED IN U,S.A. ANALYSIS OF FIRE BASIC CAUSE (CHECK ONLY ONE. Q a) EQUIPMENT FAILURE DUE TO DEFICIENCIES IN: OPERATOR ERROR DUE TO: C) OTHER C~JJSES: ~'~MAINTENANCE E~ INSTRUCTIONS NOT FOLLOWED ~ JOB PLANNING 15 18 20 ~ INSPECTION OR SURVEILLANCE ~ TRAINING ~ HOUSEKEEPING 16 19 21 ~ DESl GN ~ UNKNO~V~ 17 22 ~ OTHER EXPLAIN WHY YOU SELECTED THE ABOVE BASIC CAUSE: 23 Z4.80 SPEC FY ~ A bole bad been washed into flow bean on heater allowing gas to escape into building. It is possible that an. inspection would have revealed the defect. However sand wash out could have happened in few hours. FACTORS CONTRIBUTING TO SIZE OF LO~SS (CHECK THOSE APPLICABLE) G a) DEFICIENCIES IN: f"--I DETECTING, REPORTING OR RESPONDING TO FIRE 6 FIRE FIGHTING METHODS ~ FIRE FIGHTING EQUIPMENT 17 ' E~ WATER SUPPLY SPACING ~ DRAINAGE OR IMPOUNDING 20 I---] FI REPROOFING 21 EXPLAIN HOW THESE FACTORS CONTRIBUTED TO THE SIZE OF LOSS OTHER FACTOR: ~WIDESPREAD INITIAL FIRE 22 ~ NO CONTRIBUTING FACTORS 23 :-'n OTHER 24 25.80 SPECIFY SOURCE IZF IGNITION (CHECK ONLY ONE: IF NOT CERTAIN OF SOURCE CHECKED. CHECK ALSO UNKNOWN) G ~ ELECTRICAL ~-~ HOT SURFACES ~ STATIC ELECTRICITY 15 20 25 [~] LIGHTNING ~ SPONTANEOUS-AUTOIGNITION ~ INCENDIARISM (ARSON) 16 21 26 E~ CUTTING-WELDING E~ BACXFIRE OF ENGINES I---) PYROPHORIC MATERIAL 17 22 27 ~ FIXED FL4MES ~ EXPOSURE TO OTHER FI RE ~ UNKNOWN 18 23 28 ~ SMOKING-MATCHES E~ FRICTION ~ OTHER ,:&tectric Generator 19 24 29 30.80 SPECIFY EXPLAIN WHY YOU THINK. THIS WAS THE SOURCE OF IGNITION: ~ The damage to the building Was caused by fire rather than explosion. The fire boxes on the heaters are outside the building. It is believed that the gas ignited be fore the building was filZed with gas. '~('l'. WHAT CORRECTIVE ACTION IS BEING TAKEN LOCALLY TO PREVENT RECURRENCE? ~ Installation of erosion detectors and inspection of chokes and beans. ~rT'F. WHAT CHANGES IN COMPANY POLICIES. PRACTICES, OR DESIGNS SHOULD BE MADE TO PREVENT RECURRENCE? ~ It is recommended that erosion detectors be installed in wells that have erosion pro bl ems.~ -xq-r-[. (~) ,.~.u~.~-,,'.~~ ,,,2~.z/,~,2' DATE OF REPORT ~? ' / 1~ l, 84 Anchorage ~.._..~HEV RO N' U. S. A.._.IN C. TP, ANSMIT% .... eD ACKNOWLEDGEMENT OF RECEIP ..... MATER~AL - (ALASKA) DEPT.: PLACE: THE FOLLOt~ING IS A LIST OF F. ATERIAL ENCLOSED HEP, gIN. FD- Folded R - Rolled S - Sepia F - Film - Xerox B - Sluel~ne PLEASE CHECK AND ADVISE II~EDIATELY. O...6. A._~ INr__.,- C)PE.~.,A'I'""pP.,: ...~E. LOC..,xA Rtd6.~ WaLL i · _1-' ii i P,~OV 2 9.1.qM _ Alaska Oi.I & Gas Cons. Comm[,ssion ._ Anchorage RECEIVED BY _l i i · i'nnl I I ,In i ~ON U.$J~ INC. BOX 7-839 ,~"-'? STATE OF ALASKA ~ ALAS~,....)IL AND GAS CONSERVATION .,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 72-015 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50-283-20037 9. Unit or Lease Name OTHER 4. Location of Well 2000' $ & 50" E of the ~ Cor., Section 24, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) K.B. 20.7' 12. I 6 . Lease Designation and Serial No. ADL 21127 10. Well Number BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations ['~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). see attached. RECEIVED Alaska Oil & (~as Cons. C0mrnJssJ0n Anchorage 14. I hereb~ t~t for~.~c~rec~t to the best of my knowledge. Signed ~/~. ~, ~ ~,,,~--¢, -¢.~-~,~--~ Title Area Engineer The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission ,, / bate _~_~__~_ _f~ ~7.~_ Sub~it '~l~tent~o~s" i~ Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate 1. Moved in and rigged up Brinkerhoff Rig //58. 2. Killed well, removed tree. 3. Installed and tested Class III BOPE. 4. Pulled string IV (2-1/16" heater string), string III (2-3/8" tubing), string II (2- 7/8" tubing) and string I (2-7/8" tubing). 5. Ran Schlumberger's CET, CBL, & CNL Logs. 6. Production test #1 interval 5334'-5919', 1250 MCFD, 600 psi tubing press. produced total 9.3 bbls. water -- 1.25 BPH avg. 7. Production test #2 interval 5036'-5296', 3290 MCFD, 1190 psi tubing press. produced total 18.4 bbls. water -- 4.6 BPH avg. 8. Production test #3 interval 4392'-4975'. Test failed -communication to annulus. 9. Set cement retainer at 5310', cement squeeze #1 interval below 5310'. Squeezed 150 sx of Class G cement, reversed out 50 sx, total cement mixed 200 sx. 10. Set cement retainer at 4967', cement squeeze #2 interval 4967'-5310'. Squeezed 127 sx of Class G cement, reversed out 23 sx, total cement mixed 150 sx. 11. Set cement retainer at 4345', cement squeeze #3 interval 4345'-4967'. Squeezed 150 sx of Class G cement - overdisplaced perforations. 12. Drilled up cement retainer at 4345' and cement to 4754', fell to 4825'. 13. Perforated with Schlumberger using 4 holes per foot intervals 4764'-4778', 4679'-4697', 4482'-4492', 4392'-4400'. 14. Production test #4 intervals 4764'-4778', 4679'-4697', 4482'-4492', 4392'-4400' and original perforations from 4778' to 4967', 8700 MCFD, 1160 psi tubing pressure produced 22 bbls water I BPH avg. 15. Set cement retainer at 4105'. 16. Set cement retainer at 3904'. Cement squeeze #4 interval 3904'-4105'. Squeezed 122 sx of Class G cement, reversed out 28 sx, total mixed 150 sx. 17. Set cement retainer at 3535', cement squeeze #5 interval 3535'-3904', squeezed with 150 sx of Class G cement, reversed out trace, total mixed 150 SX. 18. Set cement retainer at 3452', cement squeeze #6 interval 3452'-3535', squeezed with 90 sx of Class G cement, reversed out 10 sx, total mixed 100 SX. 19. Set bridge plug at 3350', set cement retainer at 3239', cement squeeze #7 interval 3239'-3350'. Squeezed with 100 sx of Class G cement, total mixed 100 sx. 20. Drilled cement and retainers to 4961'. 21. Ran Schlumberger's CET log from 4961' to 3100'. 22. Set bridge plug at 3310'. 23. Perforated 3255'-3256' with 4 - ~" holes per foot using Schlumberger. 24. Set packer at 3175', cement squeeze #8 interval 3255'-3256'. Squeezed 150 sx of Class G cement, total mixed 150 sx. · 25. Drilled cement, retainer and cleaned out to 4960'. 26. Set bridge plug at 3920'. 27. Perforated 3708'-3692', 3672'-3662', 3636'-3624' and 3414'-'3362' with 4 - ~" holes per foot using Schlumberger. 28. Production test #5 interval 3708'-3692', 3672'-3662', 3636'-3624', 3414'-3362' and all old perfs from 3362' to 3894'. 5,400 MCFD 1190 psi tubing pressure 18 bbls water total O BPH last 4 hours of test. 29. Production test #6 interval 3600'-3918'. 4215 MCFD 1190 tubing pressure 13 bbls. water total I BPH last hour. 30. Ran triple completion strings, 2-7/8" string I (Long), 2-7/8" string II (Short), r-2r/3/8" string III (Heater). Had small ID cross-over. Pulled all three strings. 2 9 fll~k~ I'lii /1, £-;~.~ P. nng_ C, ommission 31. 32. 33. Re-ran triple completion strings, 2-7/8" string I (long), 2-7/8" string II (short), 2-3/8" string III (heater). Pulled all three strings due to packer failure. Re-ran triple completion strings, 2-7/8" string I (long), 2-7/8" string II (short), 2-3/8" string III (heater). Seals did not seat in string II - reseat seals. Unloaded strings I and II. Rigged down BSI Rig #58. Anticipate returning well to production by 12/20/84. RECEIVED r' OV 2 9 Alaska Oil & 6as Cons. Commission Anchorage DEPT.: · ,~-~..CHEVRON U. $.A,~C, , TRANSHITTA'- AND ACKNOt~LEDGEHENT OF RECEIPT OF HATERIAL - (ALASKA) .. FI)- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueliue THE FOLLOWING IS A LIST OF HATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IM}fEDIATELY. ,, ,, , , ~.o,v 161984 Alaska Oil & Gas Cons. Commission - ' Anchbrage i __ i°' Ii iai i i1 i i i i i i1~11 i _ m ii I iii ii RECEIVED 8Y BY C2tEI/RON U. SJ~ INC. r'-~-'% STATE OF ALASKA ALASKAOIL AND GAS CONSERVATION uOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 72-015 3. Address P.O. Box 107839, Anchorage, AK 4. Location of Well 99510 2000' S & 50' E of the NW Cor., Section 24, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) K.B. 20.7' - I 6. Lease Designation and Serial No. ADL 21127 12. 8. APl Number so- 283-20037 9. Unit or Lease Name 10. Well Number BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling Check ApprOpriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1) 2) 3) 4) 5) 6) 7) ND Tree, NU BOPE, test BOPE to 3000 psi. Kill well with 10.0 ppg brine. Pull 2-7/8" string II. Repair stinger and rerun string II. ND BOPE, NU tree, circulate hole with diesel. Set top dual packer, pressure test packer, production test string I and string II. Rig down BSI #58 and return well to production. Verbal approval from Harold Hedlund 11/13/84. RECEIVED Anchorage 14. I hereby ce~a~~to the best of my knowledge. Signed~-'~~~ Title Area F, nglneer The space below for Commission use Date Conditions of Approval, if any: Approved by Approvo~ Returned By Order of COMMISSIONER the Commission Da,e // v? Form 10-403 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,~/-'-~, STATE OF ALASKA ~~ /"b /' - ALASK. _ .AND GAS CONSERVATION ~.,,. ilSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS"/% 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 72-015 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50-283-20037 9. Unit or Lease Name 4. Location of Well at surface 2000' S & 50" E of the NW Cor., Section 24, T13N, RIOW, W.M. 5' Eievati°ninfeet~nldicateKB'DF'etc')K,B,~O,, I6' LeaseDADL ~i~n~at~°~andSerialN°' 10. Well No. BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling For the Month of October ,19.84 :12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks See Attached 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run See Attached J 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED NOV 1 6 1984 Alaska Oil & Gas Cons. Commission See Attached Anchorage 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. S'IGNED _ . TITLE Area Engineer DATE NOTE Report on this form ~s required for each calendar month regardless of the status of operations, and must be filed i~dup~icate wi'th the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate le 0 ® ® e Be 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Completed pulling 2-7/8" string I tubing. Ran Schlumberger's CET, CBL, & CNL Logs. Production test #1 interval 5334'-5919', 1250 MCFD, 600 psi tubing press. produced total 9.3 bbl~ -- 1.25 BPH avg. Production test #2 interval 5036'-5296', 3290 MCF, 1190 psi tubing press. produced total 18.4 bbls. -- 4.6 BPH avg. Production test #3 interval 4392'-4975'. Test failed -communication to annulus. Set cement retainer at 5310', cement squeeze #1 interval below 5310'. Squeezed 150 sx of Class G cement, reversed out 50 sx, total cement mixed 200 sx. Set cement retainer at 4967', cement squeeze #2 interval 4967'-5310'. Squeezed 127 sx of Class G cement, reversed out 27 sx, total cement mixed 150 sx. Set cement retainer at 4345', cement squeeze #3 interval 4345'-4967'. Squeezed 150 sx of Class G cement - overdisplaced perforation. Drilled up cement retainer at 4345' and cement to 4754', fell to 4825'. Perforated with Schlumberger using 4 holes per foot intervals 4764'-4778', 4679'-4697', 4482'-4492', 4392'-4400'. Production test #4 intervals 4764'-4778', 4679'-4697', 4482'-4492', 4392'-4400' and original perforations from 4778' to 4967', 8700 MCFD, 1160 psi tubing pressure produced 22 bbls water I BPH avg. Set cement retainer at 4105'. Set cement retainer at 3904'. Cement squeeze #4 interval 3904'-4105'. Squeezed 122 Sx of Class G cement, reversed out 28 sx, total mixed 150 sx. Set cement retainer at 3535', cement squeeze #5 interval 3535'-3904', squeezed with 150 sx of Class G cement, reversed out trace, total mixed 150 SX. Set cement retainer at 3452', cement squeeze #6 interval 3452'-3535', squeezed with 90 sx of Cla~ G cement, reversed out 10 sx, total mixed 100 SX. Set bridge plug at 3350', set cement retainer at 3239', cement squeeze #7 interval 3239'-3350'. Squeezed with 100 sx of Class G cement, total mixed 100 sx. Drilled cement and retainers to 4961'. Ran Schlumberger's CET log from 4961' to 3100'. Set bridge plug at 3310'. Perforated 3255'-3256' with 4 - ~" holes per foot using Schlumberger. Set packer at 3175', cement squeeze #8 interval 3255'-3256'. Squeezed 150 sx of Class G cement, total mixed 150 sx. Drilled cement, retainer and cleaned out to 4960'. Set bridge plug at 3920'. Perforated 3708'-3692', 3672'-3662', 3636'-3624' and 3414'-'3362' with 4 - ~" holes per foot using Schlumberger. Production test #5 interval 3708'-3692', 3672'-3662', 3636'-3624', 3414'-3362' and all old perfs from 3362' to 3894'. 5,400 MCFD 1190 psi tubing pressure 18 bbls water total O BPH last 4 hours of test. Production test #6 interval 3600'-3918'. 4215 MCFD 1190 tubing pressure 13 bbl,. water total I BPH last hour. Ran triple completion strings, 2-7/8" string I (Long), 2-7/8" string II (Short), 2-3/8" string III (Heater). At month's end, killing well to pull tubing because of small ID cross-over in string I. R E C E [V E D Nov 1 6 1911 Alaska Oil & Gas Cons. Commission Anchoraoe HEVRO N U.S.A. TRANSMITTAL ,D ACKNOkfLEDGEMENT OF RECEIPT ,. ,4ATERIAL - (ALASKA) PLACg: , FD- Folded R - Rolled S i Sepia - Film - Xerox THE FOLLOI4ING IS A LIST OF HATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IHHEDIATELY. l i ii RECEIVED BY mi I mm mml I I m I ..... · mi (~'TRON U.S~ mC.,. BOX 7.,839 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLET'ED WELL OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of Well 2000'S & 50'E of the NW Cor., SectiOn 24, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) K.B. 20.7' 12. 7. Permit No. 72-015 8. APl Number 50-- 283-20037 9. Unit or Lease Name 10. Well Number BRU 212-24 11. Field and Pool Beluga River - I 6. Lease Designation and Serial No. Beluga & Sterling ADL 21127 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Kill well with 10ppg brine 1) 2) ND tree, NU 3) 'Recover all 4) Repair leak 5) ND BOPE, NU 6) Unload well 7) Rig down BS BOPE, test BOPE to 3000 psi three strings of tubing and rerun tubing tree, circulate hole with diesel, and set packers and test zones I Rig 58 Verbal approval from Harold Hedlund 11/7/84. R E C E iV E D NOV 0 9 t ~/e~- ~ '~ ~.1~..-..,,..~a O, ~ oas Cons. Commission .1~ eC~tte~ , x'~~ ~ D~t~ Anchorage S~~s ~o.1~ o~ ~o~ 14.1 hereby c~ t~and correct to the best of my knowledge. Signed ~'/~"/'~~ ~"~'-~o ¢;~..-, ,~-~/-,,~.,, ~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Retgrned / By Order of the Commission _ Submit "Intentions" in Triplicate Form 10403 and "Subsequent Reports" in Duplicate ,.._.. CHEVRON U.S.A I,,LNC,. TRANSHIT .~D ACKNO~i. EDGEMENT OF RECEIk HATERIAL - (ALASKA) THE FOLLOI~ING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia - Film - Xerox B - Blueltne PLEASE CHECK AND ADVISE ll~(EDIATELY. i i I ,11 ' -- i- ' i ii i ii ii iiii i ii i · ii ii i _ · m RECEIVED 8Y (IHEVRON U.S.A. INC. BOX 7-839 · A I~u",i.lt'tDA~F ALASICA REMARKS ON OTHER SIDE. THIS SHEET STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION L;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 72-015 3. Address P.O. Box 107839~ Anchorage, AK 4. Location of Well 99510 2000'S & 50'E of the NW Cor., Section 24, T13N, R10W, S.M. '5. Elevation in feet (indicate KB, DF, etc.) K.B. 20.7' 6. Lease Designation and Serial No. ADL 21127 8. APl Number 50-283-20037 9. Unit or Lease Name 10. Well Number BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [~] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1) Kill well with 10 ppg brine. 2) N.D. tree, N.U. BOPE, and test BOPE to 3000 psi. 3) Pull 2-3/8" string 3, 2-7/8" string 2, and 2-7/8" string.1. 4) Repair tubing and rerun tubing as before. 5) ND BOPE, NU tree, unload and test string 1 and string 2. 6) Rig down and move out rig. Verbal approval from Harold Hedlund 10/30/84. on ¥orfn blo. ~ Dated RECEIVED NOV 0 Alaska 0il & (~a8 Cons.C0rnm~ssJ0n' 4nchorage Signed j~, t;~"~- '~~f~~_Z~''~. _ · , _ ._ _ Title Area Engineer_ The space below for Commission use Date Conditions of Approval, if any: ORIGINAL SIGiIEll ~' ~Y ~'T'~RY W, I(UGLEll Approved Copy By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,._._....,CHEVRON' U. $~A..J.,I N C. · ~P~s~[~'[ ,D AC[NO~,DOr. M~NT pr RE,,CE,If'., . H~T,ERt/~..-- (ALASKA) DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMEEDIATELY. i i i ii i i UiJI- I ! i i L __LI I 11 , I II 1, Ill I II , 11 Il I II I I I ' - I , .ill .. I I , I I I I I I I , i,, RECEIVED BY THI~ gML~T i i ii1 i iii i i _L CHEVRON U.$Jt. INC. BOX 7.839 ~ STATE OF ALASKA ~ ALASk,~ ,~L AND GAS CONSERVATION coMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER []' 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 72-015 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of Well 2000' S & 50' E. of the NW Cor., Section 24, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) K.B; 20.7' 12. I 6. Lease Designation and Serial No. ADL 21127 8. APl Number 5o- 283-20037 9. Unit or Lease Name 10. Well Number BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: · (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] ~ Perforations [] Altering Casing [] StEm ulate [] Abandon [] StEm ulation [] Abandonment [] Repair Well E~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Fo'rm 10~407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1) Set drillable bridge plug at 3310'. 2) Shoot four ½" JHPF from 3255'-3256'. 3) Squeeze holes 3255'-3256' with Class "G" cement through RTTS at 3175'. 4) Drill out cement. Pressure test squeezed holes to 2000 psi. 5) Clean out to PBTD of 4961'. 6) Set retrievable bridge plug at + 3920'. 7) Reperforate the following intervals with four ½" JHPF: 3708'-3692' 3672'-3662' 3658'-3642' 3636'-3624' and 3414'-3362' , Verbal approval from Lonnie Smith on 10/22/84 i~ ECEi VED OCT 2 4 AlasKa Oil & (~as Cons. CommJssJo~ Subs-equ,%t Work Beportecl on Form No. ~Dated ~/~ Anchorage certify that the foregoing i_s true and correct to the best of my knowledge. Signed Title Area Engineer The space below for Commission use Date conditions of Approval, if any: Approved by. ~,:tI~G':HAL SIGNE'~ Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,__.._~.C H EV RD N' U. S,A,,,.J,I N C. · TRANSMI/. _ .ND ACKNOWLEDGEMENT OF RECEI~. MATER~AL - (ALASKA) DEPT.: PLACE: DATE 0~--.'~'. THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEI~glN. FD- Folded it - Rolled S - Sepia - Film X - Xerox B - Blueltue PLEASE CHECK ANDADVISE IMNEDIATELY. ID'A. '~OLDE..I3 ,...%F_P~A., IE.A. FoLD~D C~ EV r~or, l d .,S. A..~/,~c. - 1bF_uac~A ~1VE..2. z,, CAseb CblL. P,,ua 5 ,5. C~-F /~c/N / '7. C. IBL. / VA.~{ AtSL~ ~,, i · · - ., .... F.u~ I RuN 2_ OCT 2 2 ~ 'v'c-x-- Oil & ~as Cons. Corrlmisslorl Annhqm., , , ,, -- -- i _ _ J I , I 111 I I RECEIVED BY I i II iii I iii II I · , I~IaARM~ ON OTNI~R ~10£_ TNI~t SHEET BY CHEVRON U. SJ~ INC. BOX 7..839 · .ku.,t.u"~A/'~-g AIA~V'A OO41/'~ CHEVHUN ' U.,~;-A. INC. · TRANSMIT __ .D ACKNOWLEDGEMENT OF RECEII MATER~AL - (ALASKA) t A.O.&.~.C. ~u Oe~±. ~7, ~q , , DEPT.: PLACE: .50ol · T~E FOLLOWIN~ IS A LIST OF MATERIAL ENCLOSED ~LEREIN. Folded Rolled Sepia Film Xerox Blueline PLEASE CflECKAND ADVISE IMMEDIATELY. Su~ ~'i C..~¥~oN IJ.,.,,q.A.~ INC. 0~1 hJ~uus-~Jo~,ea 0~' INTENT ii F). F C'_.F.i V F h J ~ ~ ~,~ · w ~ ~ i i Anchorage _ RECEIVED 8Y iii RE~MARI~; ~3N OTHER SIDE. THIS SHE'ET i ill i1_ I ~ BY ~.~.. ,I"~bAC. KIv'Io~J (:~[E%,'RON U.S.A. INC. BOX 7.~39 ~:~, STATE OF ALASKA ALASK,~ ,~,L AND GAS CONSERVATION u,~iv/MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 72-015 3. Address , 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 50-283-20037 4. Location of Well 2000' S. & 50' E. T13N., R10W, S.M. of the N.W. cor., Section 24, 5. Elevation in feet (indicate KB, DF, etc.) K.B. 20.7' 12. I 6. Lease Designation and Serial No. ADT. 21127 9. Unit or Lease Name Beluga River 10. Well Number BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling Check AppropriateBoxTolndicateNatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completi'ons on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1) Set a drillable bridge plug at 3,605'. 2) Set a cement retainer at 3,535' and squeeze with Class "G" cement. 3) Set a cement retainer at 3,450' and squeeze with Class "G" cement. 4) Set a drillable bridge plug at 3,350'. 5) Set a cement retainer at 3,230' .and squeeze with Class "G" cement. 6) Drill out retainers, cement, and bridge plugs and production test selected intervals to 4,967'. Verbal approval from Lonnie Smith on 10/.16/84. RECEIVED Alaska 0il & Ga~ Cu,,~:;. t;,. Anchora~:je SignedK' ~- ~' - Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 ~pproved Copy Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate' and "Subsequent Reports" in Duplicate 'CHEVRON' U. S~A:..~I N C. · TRANSMIi .ID ACKNONLEDGENENT OF RECEI, MATERTAL- (ALASKA) A.O.eT. C.C. DEFT.: ~ C) t P~ J~ 0_., O P I l"J/E b I;:~. DATE 0 e.,,-II~.,, i.b..,.I q~ THE FOLLOVING IS A LIST OF YlATEItlAL ENCLOSED HEKEIN. Folded Rolled Sepia Film Xerox Bluel~ue PLEASE CHECK AND ADVISE I~DIATELY. ~o~qc~ OF ~J-F~_NT' ,, ,~zVmo~ 0.5. A.~ INc. _ __il i i i i ii RECEIVED 8Y · ii, .y ~.~ ~SLAcKF1Q,~ _ ~ON u.$J~ INC. BOX 7-839 IIUAOV~ flu ~T.-.trO Cthlr Tbiiq _qdrrT ~ ' STATE OF ALASKA ~-'~' ~ ALASK~_.~,~. AND GAS CONSERVATION L,,~,~.~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 72-015 OTHER [] 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well 2000' S. & 50' E. of the N.W. Cor., Section 24, T13N., R10W., S.M. 5. Elevation in feet (indicate KB, DF, etc.) K.B. 20.7' 12. I 6. Lease Designation and Serial No. ADL 21127 8. APl Number 50- 283-20037 9. Unit or Lease Name Beluga River 10. Well Number BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other (~ Pulling Tubing [] (Note: Report multiple completions on .Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1) Reperforate the following intervals with four ½" jet holes per foot: 4778'-4764' 4697'-4679' 4492'-4482' and 4400'-4392' 2) Conduct a production test of the selectively perforated interval 4392' to 4927'. 3) Set a drillable bridge plug at 4105'. '" 4) Set a cement retainer at 3915' and squeeze the selectively perforated interval from 3939'-4089' with Class "G" cement. VerbaL. approval received from Mike Minder on 10/13/84. Subsequent Worl( Reported on Form No. ~¢-~-TDated ~_~./~,~2~?Alaska 0il & G[~ ou ::.;. u. The space-below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Page 6 f BRU 212-24 and kill lines and valves, pipe rams, blind rams, upper and lower kelly cocks, and safety valve to 3000 psi; Hydril to 1500 psi. Reinstall wearbushing. Set RET BP at 3918'. RIH to 3600' with test tools. Set pkr at 3600' with tail at 3615'. Open tool at 5:13 am with meal to strong blow. 1500' freshwater cushion to surface in 5 rain, gas to surface in 32 min. 10/26/84 C0mple~{~d production test of perfs between 3624' and 3894' as follows: Closed tool at 9:45 pm 10/25/84 for 4 hr buildup pressure. Bled off DP press. Fill DP with mud and shear out reverse circ sub' at 3566' with 2400 psi. Rev circ 2X DP volume through choke. Pull RTTS pkr at 3600' 3:15 am 10/26/84 and fill annulus with 6 bbls mud. Circ twice bottoms through choke and tire bottoms up through flowline. See attached. 10/27/84_ POOH with test tools. Retrieved bridge plug from 3918'. circulated bottoms up POH. Changed rams to 2-7/8". RIH to 4957' PBTD- 10/28-10/29/84 ~r[ dual 2A718" tubing and heater string. Installed X-mas tree and tested to 3000 psi. See attached. Removed BPV's. Nippled down BOPE. 10/30/84 Changed over hole from brine to diesel. Pumped diesel down each string of tubing. Set packers at 4345', 3922', and 3241'. Pressured to 2300 psi for 5 min. Pressured annulus and tested top packer and casing to 2000 psi for 15 min. Unloaded diesel from short string of tubing. Flared clean gas through 20/64 choice. f31/8, 4 Opened long string to separator. No flow. RIH with slickline to open XA sleeve at 3853'. Could not get past packer at 3245'. Encountered a reduced ID 3~" x 2-7/8" XO at base of packer. Decide to pull tubing and replace small ID crossover. Opened XA sleeve at 3170' in the long string. 11/1/84 10.0 ppg Built brine system. Pumped into 9-5/8 X tubing annulus with returns up the long string. Circulated out some gas. Circulated three complete volumes. Closed XA sleeve at 3170'. Circulated through 9-5/8" annulus with returns up the 2-3/8' heater string. Hooked up to long string and bullheaded 1 tubing volume. Hooked up to short string and bullheaded the tubing and casing volume between the top and middle packers. Well dead. Set BPV's in all strings of tubing. Nippled down tree. 11/2/84 10.0 ppg Nipple~l up BOPE and tested to 3000 psi. Pulled 2-3/8" heater string. Pulled short string tubing. Recovered long string tubing to blast joints below packer at 3240'. !1/3/8 4 Recovered all production tubing and jewelry. 10.0 ppg 11/4-11/5/84 Ran 2-7/8" ~long string, 2-7/8" short string and 2-3/8" heater string. (See attached tubing detail.) Nippled down BOPE. Nippled up X-mas tree and tested to 3000 psi. Changed outer tubing strings and annulus to diesel. Pressured up long string to 2500 psi. Pressured annulus and tested top packer and casing to 2000 psi for 15 min. Pressured long string and sheared out shear sub with 3400 psi. ~' ~ BRU 212-24 Page 7 11/6/84 Unloaded short string of diesel. Flared Clean gas through 16/64" choke. Could not flow long string through XA sleeve at 3855'. Gaslifted long string through XA sleeve at 3855' using string 2 gas until diesel unloaded. Closed XA at 3855'. (Fluid level at 3855'.) Unloaded long string (string 1) of diesel. Flowed long string. Final rate was 2.75 mmcf/d through a 20/64" choke with 1520 psi flowing tubing pressure. Unloaded. Flowed short string (string 2). Final rate was 2.6 mmcf/d through 20/64" choke with 1400 psi flowing tubing pressure. Rigged up string 2 to annulus. Unloaded diesel from annulus and heater string using gas from short string. 11/7/84 Flowed gas for two hours, shut in string 2. Attempted to bleed off annulus - produced 60 bbls diesel. Annulus flowing gas and slugs or diesel with 1100 psi tubing pressure out through a 20/64" choke. Placed a PXN plug in XN nipple in string 2 at 3284'. Annulus pressure dropped from 1300 psi to 1070 psi in 20 minutes and held - string 2 remained stable. With 1420 psi, string I had 1600 psi. Shut in the annulus- built to 1300 psi. Bled string 2 to 1000 psi. Pulled PXN plug and ran PX plug in XA sleeve at 3854' in string 1. 11/8/84 10.0 ppg Filled string 1 with diesel and pressured to 2000 psi for one hour. Attempted to bleed off annulus from 1400 psi through separator and flare - could not get below 730 psi. The shut in pressure built to 1330 psi in 45 minutes. Pressured string 1 to 2700 psi. Attempted to bleed off annulus with 2700 psi on string 1 - could not get below 110 psi. Shut in with a slow build up of 20 psi every 5 minutes. Released pressure from string 1 - annulus pressure rose + 100 psi every 5 minutes. Decide to pull tubing and change out dual packer. Pulled-PX plug from XA sleeve at 3854' in string 1. Bullheaded 71 bbls 10.0 ppg brine down string I - pressure dropped from 1050 psi to 0 psi. Bullheaded 10.0 ppg brine down string 2 - pressure dropped from 1400 psi to 1000 psi (annulus pressure remained at 1150 psi). Opened XA sleeve at 3854'. Circulated down string I and up string 2 until returns were 10.0 ppg in and out. Had no flow on string 2. Closed XA sleeve at 3854' and opened XA sleeve at 3171' in string 1. 11/9/84 10.0 ppg Circulated~ 10.0 ppg brine down string I and up annulus. Bled off trapped gas in heater string and circulated 10.0 ppg mud in and out. Closed XA sleeve at 3171' in string 1. Pressured down annulus with 1400 psi and got 700 psi on string 2. Annulus bled off but string 2 continued to flow. Opened XA sleeve at 3854'. Circulated out gas cut brine down string i and up string 2. Observed well for one hour. Closed XA sleeve at 3854'. Set BPV in all three strings. Nippled down X-mas tree. Nippled up Class III BOPE. Replaced BPV's with checkvalves. Tested Class III BOPE to 3000 psi. Replaced check valves with BPV's. Pulled 2-3/8" heater string. !1/10-!1/1,1/84 Changed rams from 2-3/8" to 2-7/8". Pulled 2-7/8" string 2 and 2-7/8" string 1 tubing. Dual 9-5/8" dual packer appeared OK but showed gas washing parallel to each of the 3t" mandrels in the packer. Lay down TIW packers and pick up Otis packers. 11/12/84 i{an-2'-'7/8" string 1 and 2-7/8" string 2 and 2-3/8" heater string. details.) (See attached 11/13/84 ~ippled down BOPE. Nippled up X-mas tree. Removed cheek valves. Changed over hole fluid from brinewater to diesel. Set Otis packers at 3292' and 4373' by ,~_._~.C HEV RO N U. S,'A.~~I N C. · TRANSMIT'..__.,? ACKNOWLEDGEMENT OF RECEI.! MATER'[AL- (ALASKA) ~o, A oc_~~ DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia - Film X - Xerox B - BXueline PLEASE CHECK AND ADVISE IMMEDIATELY. BF_L.UtTA J~l~/~. OH~T Or~,~ gr &..C.,OPI~ , -- mm-' RECEIVED BY m m II~'UAQK(C nM nTM~I~ ~,nl: TMI~ -- ~ON U.$JU INC. BOX 7.839 m_ ~ STATE OF ALASKA ALASK,~ U,L AND GAS CONSERVATION ~,,..,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 72-015 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 50- 283-20037 4. Location .of Well 2000' S. & 50' E. of the N.W. Cor., Section 24, T13N., R10W. , S.M. 5. Elevation in feet (indicate KB, DF, etc.) __ K.B. 20.7' 6. Lease Designation and Serial No. ADL 21127 9. Unit or Lease Name Beluga River 10. Well Number 212-24 11. Field and Pool Beluga River - Beluga and Sterling 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1) Set cement retainer at +5315' and squeeze perforations at 5334' - 5345' with Class "G" cement. 3~ 2) Set cement retainer at +--4975' and squeeze perforations at /032' - 5036' with Class "G" cement. 3) Set cement retainer at +4350' and squeeze perforations at 4392' - 4400' with Class "G" cement. Drill out retainer and cement to +4975'. Production test interval 4413' - 4927'. 4) 5) Verbal approval from Lonnie Smith 10/11/84. S bsem~e?'t Work ltepo~tecl 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: 6Rllllil[ SlJJl[O III [ONItlE C. SMITI1 Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · ' * STATE OF ALASKA ,..-.,'-,, ~ ALAS;~i AND GAS CONSERVATION' ,MISSION MONTHLY REPORT-OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] · 2, Name of operator ?. Permit No. Chevron U.S.A. Inc. 72-015 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of Well at surface 2000' S & 50' E of the NW Cor., Section 24, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. K.B. 20.7' ] ADL 2112.7 8. APl Number 50- 50-283-20037 9. Unit or Lease Name Beluga River 10. Well No. BRU 212-24 11. Field and Pool Beluga River - Beluga & Sterling For the Month of September ,19 84 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Rigged up Brinkerhoff Rig #58. Commenced operations 9/20/84. Killed well. Pulled string IV (2-1/16" heater string), string III (2-3/8" tubing) and string II (2-7/8" tubing). Recovered string I (2-7/8" tubing) to 4621'. Fishing for remainder of string I 2-7/8" tubing at month's end. 13. Casing or liner run and quantities of cement, results of pressur9 tests N/A 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A :1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED ~~~ T,TLE Area F. ng,.eer DATE.. ' _V'/~' NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filecl~n dt~licate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ~-~-~-'~ STATE OF ALASKA ~" ALASKA OIL AND GAS CONSERVATION OuMMISSION SUNDRY NOTICES AND REPORTS ON WELL8 DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 4. Location of Well 99510 7. Permit No. 62-033 8. APl Number 50-283-10025-00 9. Unit or Lease Name _~elu~a River 2015' S. & 595' E. of the N.W. Cor., Section 25, T 13N., R.9W , S.M. 5. Elevation in feet (indicate KB, DF, etc.) 15' K.B. 12. 6. Lease Designation and Serial No. ADL- 17658 10. Well Number BRU 212-25 11. Field and Pool Beluga River - Sterling and Beluga Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing I-'] ~ Perforations Stimulate [] Abandon I"] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [~ Altering Casing [] [] Abandonment [] ~ Other I'-I 13. DesCribe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). SEE ATTACHED RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify~that the foregoin~ is true and correct to the best of my knowledge. Signed j~. I~- ~ Title Area EnKineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1) Moved in, rigged up Brinkerhoff Signal Rig 58. NU BOPE and tested to 3000 psi. 2) Killed well with 10.0 ppg 3% KCL and saturated NACL brine. Pulled production tubing. 3) Logged with Schlumberger's CBL-CET and cased hole neutron from 4156' to 2500'. 4) Production tested.perforations at: 4105'-4111', 4078'-4068', 4056'-4060' ! 4020'-4024' 4008'-4014', 3732'-3734' 3650'-3668' 3437'-3458' and 3420' 5) Perforated and production tested at: 3338'-3344' 3815'-3825' 3866'-3876' and 3901'-3921'. Reperforated 4008'-4014'. 6) Cement squeezed perforations 3420' 3437'-3458' 3650'-3668' 3732'-3734' 3815'-3825', 3866'-3876' because~of sand and water production. Logged with Schlumberger's CBL-CET from 4150' to 2250'. 7) Ran 2 3/8" production tubing with packers at 3890', 3393' , and 3260' . Ran 2 3/8" heat string to 2034' Nippled down BOPE and nippled up tree. Circulated out brine with diesel. Set hydraulic packers. 8) Unloaded diesel and production tested Sterling perforations at: 3338' to 3344' and Beluga perforations at: 3901'-3921', 4008'-4014', 4020'-4024', 4056'-4060', 4068'-4078', and 4105'-4111'. Maximum rate 3.2 MMCF/D at 1100 psi. Closed selective sleeve and isolated Sterling perforation 3338' to 3344'. Production tested Beluga perforations 3901'-3921', 4008'-4014', 4020'-4024', 4056'-4060', 4068'-4078', and 4105'-4111!. Maximum rate 3.9 MMCF/D at 1120 psi. 9) Shut in well. Rigged down and moved off rig.' 10) Installing production facilities in preparation to produce from the Beluga formation. Estimated completion date: 10/1/84. RECEIVED SEP 1 81984 Alaska Oil & Gas Cons. Commission Anchorage ~ CHEVRON' U.$.A,-,,INC. TRANSNII,...., AND ACKNOt~EDCENENT OF RECEIP, JF NATERIAL GTA-f-~ ~F Ab/~SKA ~cs: 3ool P0c, e..uP~ ~dF__ DR~A,'qO~I. AI~. · R - ~11ed S - Sepia F - Film X - Xerox B - Bluel~e THE FOLLOWING TS A LIST OF I~IATER:I:AL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE :I:I41~DIATELY. coutJb~,.i 1~ ~L-UCTA 6~LUC~ ! Id OT~ CF_.5 ¢. R F___eOk~-S OF ~3~bUC. A RtV~ V~! gLL.~ BRLI Od IA/~. -- IN TP_..IPL-,oAT& It _ ii ii i ii ii i i i · . __I'F Il ,,, ._l R'EL iVED ' JUN 2 2 i Ul · i i i · i iii Alaska 0il & Gas Cons. Commission · - A~,~;,v,"~C, ..... ii RECEIVED ElY iiiim ' -- ii i I i ii i · i i · i I II Il - ii i , REMARKS ON OTHER SIDE, THIS SHaT ii ii BY ,~.. P. '[SLAcKMoI~ ~O1NT U.$JL. IN(]. BOX 7,839 'ANCHORAGE, ALASKA 09510 ?'-" STATE OF ALASKA ~ ALASK, )IL AND GAS CONSERVATION (..VlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WELL E~ OTHER r-I 2. Name of Operator 7. Permit No. CheVron U.S.A. Inc. 72-015 3. Address 8. APl Number ?. O. SOX 107839, Anchorage, AR. 99510 50- 50-283-20037 t, ocation of Well 2000' S & 50' E of the ~ Cor., Section 24, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) S 20 12. I 6. Lease Designation and Serial No. ADL 21127 9. Unit or Lease Name Beluga River 10. Well Number BRU 212-24 11. Fiel~and Pool Beluga River- Beluga & Sterling Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing r-I · Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made , [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. This work will begin on or about August 6, 1984 Subsequent Work Beported _.~/..~~ on t~onn No. ~~- Dated RECEIVED JUN 2 2 1984 Alaska Oil & Gas Con~, Commission Anchom~ Signed~-"/'-C~" ~, Title Area Engineer The space below for Commission use Conditions of Approval, if any: Approved by. ApprOved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PROPOSAL FOR WKI,L OPERATIONS- PRO 316-..1 BRU ~ZI2-:Z4 ]LKMKDIAL ,JOB 1984 WELL: BRU 212-..24 Z000.46' South and 50.44' East of the LOC.: N.W. Corner of See 24 T13N R10W SB&M FIELD: Beluga River Unit TYPE WELL: Produein~ Gas Well OBJECTIVE: Pull tubing, locate water production, isolate or squeeze off water, rerun tubing, and return the well to production. WELL DATA:K.B. 20.7' T.D. 6,380' PBTD +5,945, CASING: 9 5/8" to 6,376', 13 3/8" to 3,202', 20" to 365', 30" to 30" LINER: None TUBING: Four strings (see attached mechanical) PKR. 6 packers (see attached) PERFORATIONS: See attached list Notes: (A) (B) String I has a plug in the Cameo D "nipple" at 5,324', sand fill on top of the plug to 4551', a lost CE¥ valve in the 2 7/8" tubing between 5,324' and the top of the sand fill at 4,551'. A pack off is set across the 2 7/8" XA sleeve at 4170' and a plug is set in the 2 7/8" position 3 Otis nipple at 3924'. The. 9 5/8" easing may be eollaps~ed Duri~ th~ ortgxn mp n this ar~a~had to be swedged out in order to set the 9 5/8" Baker Model D packer below it. Care should be taken when pulling or running any tOOls through this section. (c) 9 5/8" CASING DwrAH. Deseripti,on Len~h Size Weight Grade Thread KB Depth Above KB - 3.52' Top 21 Joints 855.42' 9 5/8" 43.5# P-110 Buttress 851.90' Next 17 Joints 626.24' 9 5/8" 43.5# S-95 Buttress 1478.14' Next 42 Joints 1804.25' 9 5/8" 43.5# N-80 8rd 3282.39' Next 21 Joints 858.16' 9 5/7" 43.5# S-95 8rd 4140.55' Stage Collar 1.75' 9 5/8" 8rd 4142.30' Next 14 Joints 555.73' 9 5/8" 43.5# S-95 8rd 4698.03' Next 40 Joints 1677.9'/' 9 5/8" 43.5# P-110 8rd 6376.00' On Hook 6379.52' Blowout Prevention Consideration 1) Potential Problems: Gas: The subject well is a completed gas well with three producing tubing strings and a fourth heater string. All three production strings are in some_ degree of eomm_ . _unieation with eael~~oth~r~t union-own 'dePths. This ~ RECEIV D JUN 2 2 19~,4 2) 3) will_be di__ffieult to lan and ~as miRTation to _the surface e~ be expected at any tim~ aftee-0~p~ati0ns haVe eommen~ed. Extrem~ ~'aution mUSt be exercised While Ici!ltr~ and pp!!it~ this weU. Numerous circulation periods will be required. Drilling crews should be alert at all times for gas kicks and be familiar with our procedures for handling kicks. The hole should be kept full at all times and care exercised not to swab the well in while pulling. Have sufficient barite on location to weight up the mud system two times the mud system volume. Lost Circulation: At the programmed mud weight of 10.0 to 10.5 ppg, lost circulation is not expected. While drilling this well ?0 bbls. of 10.3 ppg mud was lost at 3770'. Anticipated Formation Pressures: The maximum estimated gradient is 0.48 psi/ft. (See the mud detail for estimate individual zone pressures.) PROGRAM: 1) 2) Prepare the location for workover rig. Build an earth flare pit away from the rig -no reserve pit is allowed. Prior to moving in the rig, pull the plug from the 2 7/8" Otis position 3 'S' nipple at 3924', and the Otis pack off from the 2 7/8" Otis XA sleeve at 4170' in string I. Recover the lost Camco MMA CRV valve in string L Note the CEV valve is believed to be at +4554' with sand on top. Attempt to recover the valve by' bailing down to th~ valve with wire line. If unable to bail the sand, wash down to the valve with coil tubing. After recovering the valve, wash out with coil tubing the remaining sand down to the plug in the Cameo D nipple at 5323'. Kill string I. Use 2% KCL Brine weighted to 10.4 ppg with CaC12 as a circulating medium. ~T~.ak~e returns through an adjustable choke and a Xas busterYseparator. Flare ~ and reuse K CL brine solution. POOH with esil tubing.~ Kill s~ing H an~iii-with KCL brine by opening the 2 7/8" XA sleeve in string I at 3913' and the 2 7/8" XA sleeve in string II at 3513', pumping down string I and taking returns up first string H and then string III. Estimated volume of KCL brine: 5323' of 2 7/8" Tog. at 0.0058 BPF 3895' of 2 7/8" Tog. at 0.0058 BPF 3258' of 2 3/8" Tbg. at 0.0039 BPF 925' of 2 7/8" x 9 5/8" at 0.0664 BPF Sub total Excess Total volume needed 30.9 bbis. 22.6 12.7 61.4 bbls. 127.6 bbls. 72.4 ~ bbis. Set OCT pump through back pressure plugs in all tubing strings. 3) Move in and rig up rig. Set up to recover all fluids and cuttings. 4) Mix up a lightly treated chrome free Lignosulfanate mud system with: 10.0 - 10.5 ppg 30 - 45 see/qt vis 4-6 ec fluid loss (See mud program for greater detail.) RECEIVED JUN 2 2 19~4 Alaska Oil & Gas Cons. Commission Anchorage 5) ?) 8) 9) 10) 11) li) 16) l?) Pull all back pressure plugs. Open 2 3/8" XA sleeve at 3207' in strtn~ IlL Kill all strings and the tubin~ x 9 5/8" annulus by circulating mud down string I out th~ the XA sleeves at 3913' in string I~ at' 3513' in strir~ II, at 3207* in strin~ I~ and up the tubin~ x 9 5/8" annulus. Circulate through each tubing Note: Use 50 to 100 bbls. of fresh water flush string until the well is dead..____ ahead of the mud. · Set OCT pump through back pressure plugs in strings I, II, !1I, and IV. N.D. tree. Set' Gray Tool blanking plugs or similar equipment is all the tubing hangers. N.U. Class 11I BOP and pressure test BOPE equipment to 3000 psi. Alert AOGCC and BLM 24 hours prior to the test. Have 2 1/16" pipe rams in BOP, have 2 3/8" and 2 7/8" pipe rams on location. Have 2 7/8" x 2 7/8" dual pipe rams located and available for running completion strings. Remove the blanking plugs. Circulate out any gas bubbles and pull string IV (2 1/16" 3.4# N80 10rd). Change to 2 3/8" pipe rams, release J-latch on string lII, circulate well dead and pull string llI (2 3/8" 4.7# NS0 EUE 8rd). Change to 2 7/8" pipe rams, release string H at ce joint built into triple packer at 3243', circulate the well dead, pull string #II (2 7/8" 8.5# NS0 EUE 8rd). Release string I at Brown CC joint at 3,232', circulate the well dead, pull string I (2 7/8" 6.5# N80 EUE 8rd). Install wear bushing. Pick up drill pipe and RIH with a CC jt. retrieving tool or overshot with jars and collars as needed. Work over the CC jr. and release the packer at 3,243'. Note: (All the hydraulic packers are 40,000# straight pull release. All safet~nts are 50,000# straight pull release.) Circulate the well dead and POOH. Pull the tubing slowly in order not to swab in the well. Recover the remaining hydraulic set packers and jewelry. Note~ Watch for collapsed casing at 4,621' to 4,625'. Clean out to the top of the Baker Model D packer at 5,309' with a bit and easing scraper. Run a cement bond evaluation tool and a multispaced neutron log from 5,309' to 2,500'. Rig up to production test the well using a mobil test separator and heater. ~.Lav .& flare Itne~o_9i~ Rig up a Baker tank or a test tank to recover any fluids while unloading the well. Recover the unloading diesel and reuse if possible. Production test the intervals listed below using ~ill pipe. (The test intervals may change after review of the logs.) Use Baker 9 5/8" retrievable packer and a 9 5/8" Model O lock-set retrievable bridge plug or similar equipment. (Use a Baker stimulation tool or similar equipment and a diesel cushion if the well will not flow with a full column of diesel. R ~ C ~V ~ D JUN 2 2 19Bz Alaska 0ii & Gas Cons. Commission Anchorage General test procedure.* Set the bridge plug (if needed) at the required depth, pull up hole to the required packer depth, displace the mud out of the tubin~ with diesel, set the packer and rig up a test manifold. Unload the diesel and mud into a Baker or test tank until gas reaches the surface, turn the well into separator and flare the dry gas. Obtain four Separate flow rates of a minimum of 2 hours each after the well cleans up. First rate to be 0.5 MMCF/D and the other rates are to be determined by the results of the previous test. (Notes Excessive draw down on other wells -500 psi. less than static - have caus---~'(~ sand production. Keep the maximum draw down to less than 400 psi. of the initial 0.5 MMCF/D.) Record production rates, water production, tubing pressures, choke sizes, final static pressure, etc. After the test, kill the well, release the packer and bridge plu~ and pull up hole for the next test. Test Zone Interval Bridge Plug Depth I FGHI 5919'-4392' None 2 E 4328'-4049' + 4350* 3 CD 4002'-3624' + 4025' 4 AB 3582'-3278' + 3600' Packer Depth +4350' + 4025' + 3600' + 3200' Supplementary completion program and tubing detail to follow. A) The tentative completion design to segregate the zones are as follows; Zones packer (MD) Type packer FGHI + 4345' Single Hydraulic E + 4023' Single Hydraulic CD + 3600' Dual Hydraulic AB + 3264' T~iple Hydraulic J. A. CONN 3/28/84 Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 C. F. Kirkvoid Area Operations Superintendent Production Department December 28, 1979 RES -i 3 EN~ t 4 ENG -T EO[ ..... ---T-3~-C~L ( I S.rAT'r' c I CONFER: GAS WELL OPEN FLOW POTENTIAL REPORTS BELUGA RI'VER UNIT, ALASKA Mr. Hoyle H. Hamilton, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, A1 aska 99504 Mr. Rodney A. Smith Regional Oil and Gas Supervisor Alaska Region U.S. Geological Survey P. O. Box 259 Anchorage, Alaska 99501 Gentlemen' Enclosed for your records are two copies each of Gas Well Open Flow Potential Reports for the following Beluga River Unit Wells. These 4- point tests were conducted during September and October, 1979 and represent initial tests for each respective zone of completion. Well No. Date of Test BRU 212-24 String 1 BRU 212-24 String 2 BRU 212-24 String 3 BRU 244-4 String 1 BRU 241-34 String 1 September 26, 1979 September 25, 1979 September 27, 1979 October 2, 1979 October 1, 1979 Very truly yours, CHEVRON U.S.A. INC. Unit Operator C. F. Kirkvold Area Operations Superintendent RGH:sr Enclosures ! O0 Years Helping to Create the Future GAS ·,ELL OPEN FLOW POTENTIAL TEST Test Initial. ~ Annual [-'] 'ORT Special I · I Field . Reservoir ' Test Date · Beluga River Sterling Formation I / . 9-27-79 Operator { Lease { ¥~'ell Xo. Chevron U.S.A. Inc. ~ Beluga River Unit {BRU 212'24 County ]Loc[tti,,n Completion Date I ?oral Depth T/Par Producing Kenai Section 24, T13N, R10W, SB&M 10-23-73I 6380 132 3~'~!35 . Producin~ Thru [ Re~em'0i? I Wellhead I CSO. Sizei ,Vt/Ft. I LD. Iset~ 6376' ~nG. ~ CSG. ~-~,,, ' ~'~"'~ 9--5/8 43.5 8. 755 Plugged to 5945' X - 76 '~ 68 'F (Separator) Length (h) 'Ralto MfF per Bbl. Liquid (Apl) 2-7/8 ~.7 / .375 ~.995 3258 0.555 ..... ' Pipeline Connection ~ Type Taps Chugach Electric Assoc~aC2on F~ange 24 Multiple Completion (Dual or Triple) St~!~ng 3 ] Type production from each zone iBSERVED DATk ) Flow Data (1) ( 2 ) Time (Prover) ' Orifice ~ ..Static Di'fferenti;~l' Bot6om- cas,!ng Flowing No. of Flow (Line) Plate Pen Pen Hole Press. Temp. Re~d ing Pres sure psig 'F SI Hours Size S i. Z e Re ad ing "J 1633 pACKER ~. 2. .... 0 4.026 1.,750 5.90 2.20 1620 " 94° ~. 2.0 . J 4. 026 1. 750 5.88 3.50 , .1611 " 94°, ~. 2.0J 4. 026 'j 1. 750 5.86 5.30 1602 ' " 91° 4. 2.0 J 4. 026J 1.750 5.84 6.95 '159.3 ...... " .... 870 FLO%V CALCULATIONS Coefft' S t ati c Flow Temp. Gravity Compress. No. cient X Pressure Factor Factor Factor Rate of Flow (24 Hr.) Differential psia Ft Fg Fpv Q MCF/D ~. 92,.58~ 12.980 Coefficient.., ~ere calcul ~ted according to 1202 ~. 92,563 20.580 "Bulleti~ Tf',-561", publi.,~hed bY the California 1904 .~. 92,870 31.058 Natural Gas Asso.ciation ~nd adj.usted t!~ 14.65 psia. 2884 i. 93,290 40.588 3786 , PR~.ssra~ CAnCOLAT,O,WS (3) P P w P: F q (F Q), (F Q)-" X 1-e'~' Pwf2 Ps2 - Pwf 2 pCal' w ..p (psia) :t c c c -.w p t x 106 e ~. - .... 2' 624 '42,404 - - ~.. - .... 2.596 70,226 - .~. - _ I - - - 2.567 99,402 - ~. . ..... 2.538 128'~365 - - Absolute Potential I Il 80,000 A[CF/D 1. 007 CERTIFICATE: I, the undersigned, state that 'I' am the Areal Eng. of the Chevron U.S.A, '.Inc. (company),' and that I am authorized by said company to make this report; and that this report was pre- . , the facts st~erein are true, correct and complete to pared under my supervision and direction and that . (1) Measured from 100"x2000 psi' Barton si Re co rder , (2) Pressures measured with bottom-hole recorder hung at 3250~ and adjusted to 3401~ (mpp). psia. (3) Pwf -- Bottom-hole flowing pressure (psia) Ps ~.Bo,~tto. m-hole static pressure (ps±a) Alaska Oil and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4-Point Test) Form No. G-1 Authorized by Order No. 1 Effective October 1, 1958 -( 10.0 :_ : . : : : - ~ -. :L~'~::~--;:-::'---F:: ;"-:~:.::~:.:ci-::.-:-~..-:h-:b. . : .... ~ ~; . : . '.. ~ :c--: ::::::¢:-:':-=?z:-~'~: ........ ;:.-?".-'~::::F':'~-'::~::.:;-: -;---?--::-:':¢:' '¢:.'-~:::.~:.- :. .:-::%: '.: : 2.5 ..... ' .......... 2 ................ ;--- ' ..... ~ , ......... . ....................... : : : :_:u:: :':~:~zzt_::-:':':;%;::x.-$-:?:::_~::':::~_.::~:::c:::t'.:~ .: - ::.z-{ : .':.':.; "~" ~ .. :-:': ' : ":':': ............ ~ .--- : ': - ~ ::._., · ; ;! -' .... - .............................. . ........ --_:- _...- :_~ .... - . . . ............. : ....... . ..... : _ 1._: ; L iZ'. L.LZ; ........... L..._~ -;i--,]-!-:~ .... [ -L %L.;.'; ..... ' ' : ':;: '::.L ,..: '":'.,. ,r ~ ~ . . . ~ : -. -;-- [ - .. f -- : .... k l .......... :..-: ...... : . : . ; , : ; ;:~.-.. ..... ; '; ,. .......: -,. ................. ~ . .4 ~.. ~.h:_L' :~.:~_.~._.z4~ ~ 4:- ....... . . . %-4 :::~-g---%--7 L4_ L_::.,_.2; ......... : - - ....... ' .......... ".,- ........... ~::.';;:C-TF:::i::::]:::L : - : :; ::::~-'." BELUGA ~ZVE~ UNZt 212-24 ...... z .... ~ .._ ; ~ . ;...~ ........ ; .............. ~ .............. ~ .... ~ .... , .-, ......... ............. ~ .......... ENGR RGH DATE 9-79 I II I I o6o 0.01 1000 Q MCF/D GAS ~E:LL OPEN FLOW POTENTIAL TEST 4-POIXT TEST Test Initial. ~] Annual [~] Special [--] Field [ Reservoir · Beluga River Beluga Formation Operator ] Lease Chevron U.S.A. Inc. Beluga River Unit County ] Loc/trion Kenai Section 24, T13N, R10W, SB&M · Producin~ Thru CS0. slze [ %Vt/Ft. [ I.D. [9--5/8 43.5 8.755 Test Date 9-26-79 Yv'ell Xo~ BRU 212-24 Completion Date { Total Depth 10-23-73I 6380 Set @ 6376' Plugged to 5945' T/Pay ] Producing 64 - 2 Re~erv0ir ] Wellhead TBG. [ CSG. Temperature ' Temperature X 85'F 67°F ' TBG. Sizet i.O.D. I.D. [ Set @ [ GasGrayity ].Avg. Yrod. [ . GL i Gas-Liquid llydrocarbon ] Gravi'yof ~ (Separator) Length (L) -Ralio .MCF per Bbl. Liquid (Apt) 2-7/8 6.5 2.875 2.441 5922 0.555 ...... Pipeline Connection { Type Taps Chugach Electric Association [ Flange %Vt/Ft. Multiple Completion (Dual or Triple) String 1. (long { Type production from each zone string), of triple completion. [ Dry Gas O~SE~VED DATX Note: Production is through a sleeve (1) Flow Data (1) (2) at 4170' Time (Prover) ' orifice .Static Di'fferenti;ii B6t tom- Ce.sing Flowing .~o. of Flow (Line) Plate ~ 'Pen Pen Hole Press. Temp. Hours Size Size Readin~ Read~n~ Pressure Dsig 'F sr ~ '-{ ~ 1640 Packer -- , , ~. 2.0 4. 026 2. 250 5.90 3.40 1618 " 82° ',[ ..... 2.0' I 4.b26 2.250 5'90 4.75 i601 " al° ~. "2.0 .....! 4.026 2.250 5.90 6.40 1581 'i 79o .~: 2.0'" {... 4.'026 2.250.... 5.96 { 7:30 1562 " 78° FLO~.V CALCULATIONS , . , Coeffi- S t at i c Flow Temp. Gravity Compress. No. cient X Pressure Factor Factor Factor Rate of Flow (~4 ~r.) Differential psia Ft Fg Fpp Q MCF/D ~. 161,367 20.060 Coefficients were calcul~lt~d acc0rdin~ to 3267 ~. 161,565 28.025 "Bulletili TF--561", publi.,~hed by the Cslifornia 4528 s~ 161,963 37.760 Natural. Gas Association ~nd adjusted t~ 14.65 psia. 61i5 162,163 43.070 6984 PRESSrgm CALCULAT,ONS (3) Pwf2 P f2 ps2 Cal. w (psla) P~ F Q (F Q): (F Q)-" X 1-e's P%~ - P p :t c c c ~%v t x 106 ~ ........... 2-619 71,676 .- 2. - - - - .- ... 2.563 ..12~,399 - .~. - - - - .. - 2. 500 190,039..' - ~._ - , .. - - - .- 2,4~0 .249...,756 .- Absolute Potential I ll 30~.000 ~rCF/D . 0,614 CERTIFICATE: I, the 'undersigned, state that I am the Areal Eng. of the' .Chevron, U., S, A. ' Inc. (company),' and that I am authorized by said company to make this report; and that this report was pre. the best of my knowledge. · (1) Measured from 100"x2000.' psi Barton Re co rde r (2) Pressures measured with bottom-hole recorder hung at 4150' and adjusted to 4046' (mpp). psia. (3) Pwf = Bottom-hole flowing pressure (psia) Ps = Bo,,t:tom-hole static pressure (psia) pared under my supervision and direction and that the facts stated therein are true, correct and complete to Signature Alaska Oil and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4-Point Test) Form No. G-1 Authorized blt Order No. 1 Effective October 1. 1958 ./- 10.0 ~-4 i.': ..................... ' - -: :': - ': ~': '- -~,.,':::t:::'::''i .... .,- ..... ~:7;.~ : ' ' :~ ' ... ~. :.~, ', ......., ~,_. _ ':-;:::~-:-: ::::::::::::::::::::::: . ~ .... ----,---~ .... o .... ~ ..... ~ ...... ~ ...................... ; ................. k ............................... . . . .. . : .... ; 8 ~ ........ - ....... 7--L.---~ %--.: ~--Li .............. ~ ........................... ~: ........ I '-.: .... .' ! ; [:: ..... , . . : ........... - ..... . -':-::-7r:':"r'-z'~: .... } ..... '- ": ..................... ......... ~:'~;i'['~ ' ' ~ :~; ~":~:.~. ;: ':":" .... ' ,:: ' ' .;" ::. ~'"!-' , ~.: I ~' :2L'; : - - . ..... :-: ~ : i':'':::-:":' ~ 6hewenU.S.A. Inc. ~ [-' ..... 7. [, 7' .-]"-['717[.;. ~ , ' . '- . ! -~'t--F 7-T'-;' ~ ~slemt~¢ : / ';'-~;;-; :':'fl;:,'::;':.:; ":~:t..~ ':;'".: '' ;-; - . , =.s~ ............ :/. ! .... [..~._~ . ¢ ...¢ ~ ......... .. ST~ZN6 ~ , . ,5 ................. ENGR. RGH DATE 1000 ~.'s :~ ~.~ 3 .... ~ -~ 10,000 .......... nn ..... For~ ! 0-403 REV. 1-10-73 Submit '*! ntentlons" In Triplicate & "SUbsequent RepOrts" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL i i OTHER 2. NAME OF OPERATOR Chevron USA, Inc. ~, ADDRESS OF OPERATOR P.O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL Atsu~ace 2,000.46' south of northwest corner, Section 24, T13N, R10W, SB&M, and 50.44' east at right angles. ]3. ELEVATIONS (Show whether DF, RT, GR, etc.) 77' GR 14. 5,_~_ ,PI NUMERICAL. CODE 50-283-0037 6. LEASE DESIGNATION AND SERIAL NO. ADL- 21128 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Beluga River Unit 9. WELL NO. BRU 212-24 10. FIELD AND POOL, OR WILDCAT Beluga River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 24, T13N, R10W, SB&/,! 12. PERMIT NO. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other)L ~U~ Well On P~O~llr~--ion SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or RecomDletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Prior to January 1, 1979, we intend to initiate production on completion string #2 (perf'd interval.: 3552'-3894') and completion string #3 (perf'd intervals: 3278'- 3494' & 3502'-3524'). Prior to obtaining open-flow-potential tests on each string, it is planned to produce the well for_+60 days to allow production to clean-up and stabilize. The open-flow-potential tests will be obtained and reported as soon as practical after the clean-up period. RFr"F VFD ~-~., ..... C (This $1~ace for State/~lce use) APPROVED BY/~-~, ~'"~~T'ITLE Petroleum Engineer DATE CONDITIONS OF APPROVAL, IF !2/8/78 See Instructions On Reverse Side ~ ~.~of ALASKA DEPARTMENT OF NATURAL RESOURCES DiviSion of Oil' and Gas Conservation TO: J--- FROM: MEMO TO FI LES Harry W. Kugler Pet roi'eum Geologist DATE , June 13, 1977 SUBJECT: Be I uga Ri vet Fie I d Dave Courtis, Union Oil Company of California, called this date to report that there were no mud logs in the State files of the following wells: Socal BRU #232-4 Completed in .1963 Socal BRU 212-25 Completed in 1962- Socai .BRU 233-27 Completed in 1963 Completed in 1973 Completed in 1974 He stated that he believed our regulations are such that we should request Socal (Chevron) submit t, hese logs if they were run. I reported, after consultation wi th the Director and staff members, that our interpretation of the regulations were not the same and we would not require the'mud logs. Upon hearing this, he stated he would turn the matter over to Union's land department for their interpretation and the land department would be in touch with us. TRANSMITTAL AN~KNOWLEDGEMENT OF RECEIPT OF M''~-~RIAL - (ALASKA) FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL- HISTORY LOG 2" 5" ! ~o---5' ~o0 1~o c~ L I~re o o [~ CDL P~oo / REMA S ON OTHER SIDE, THIS SHE'ET TRANSMITTAL AND AC~"1LEDGMENT OF RECEIPT OF PtATERi ~ALASKA) ; Ur. 'r. p,. Marshall TO: ..... Ctato o! Alaska DEPT: DMslon of Oil & Gas ---,, 3001 Porcupine Drive , I:'LACE: ~ Anchorage, 'Alaska 99504 · . THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREWITH. PLEASE CHECK AND ADVISE I}flVfEDIATELY. DI¥:'_,!C,I~ C.,F C:tL AND GAS. /.J~CHOR.'V'~ E Received and checked by: TtLANSMiTTAL AND ACKNO%,~?JEDG~NT OF RECEIPT OF MATERIAL- (ALASKA) PLACE:_ .~0 / /~,~'_~.~.~'//~/~ D~ ' - THE FOLLOWINC IS A LIST OF ~TERIAL ENCLOSED HEREWITH. PLEASE CHECK AND ADVISE I~fi~fEDIATELY. CO~LETION PJ£PORT - NEW WELL STD,.NDARD Oil, CO!..L.~A~,,nf OF CALIFOFJ~IA, WESTERN O~?~LTXONS AREA: West Side Cook Inlet PROPERTY.. Beluga River Unit I%n~LL NO.: BRU 212-24 LAND O]~FI~CE; Anchorage LEASE NO. ~ ADL 21128 API NO,: 50-283-20037 LOCATION AT SUPG,'ACE: 2000.46' South and 50.44' East of the Norch~est Corner of Section 24: T-13-~l, R.-10-W, SB&M LOCATION AT TOTAL DEPTH: Same as surface ELEVATION: 98' KB. KB to ground level is 20.7' DATE.: . J. L. RO?IL~'~D -A.PvEA DRILLED BY: R. B Idontgomery Rig #33 ) ' :~:~J~CED DRiLLii,~G: August 19,1973 DATE CO~-~LETED DRILLING: October 23, 1973 DATI~ OF INITIAL PRODUCTION: Shut-in 6380 ' PLUGS: EZ drill pez/uanent bridge p].ug at 5990' capped with c~ent to r.,~, . CASING: 30" Driven to 79' ' ~0" Cemented at 365' 13 3/8" Ce~',ented at 3,202' 9 5/8" Ceracnted at 6,376' ' * JONK: ~.;on e LOGS: Schlumberger Dual Induction-Laterolog Run #1 365' - 3104' Run #2 3104' - 3204' Run #3 3201' - 5992' Run #4 5800'.- 6373' Schlumberger Borehole Compensated Sonic Log Run #1 365' -3202' Run 92 3202' - 5988' RUn ~3 5800' - 6375' Schlumberger Compensated Neutron Formation Density Log RUn #1 362' - 3204' Run 92 3202' - 5996' Run 93 5800' -6378' Schlumberger Proximity Log -Microlog Run ~1 3002' - 6000' Run 92 3202' - 6378' Schlumberger Dipmeter .3200' - 6000' GO International Gamma-Ray Neutron Log 3100' - 6323' GO-International Cement Bond LOg Run ~1 3100' - 6320' Run ~2 3150' - 3300' Mud Log 430' - 6380' FORMATION TESTS: Formation Test #1 Formation Test #2 Formation Test #3 Formation Test .$4 Formation Test #5 CORES: Core #1 Core #2 Core #3 Core 94 3289' - 3349' 3349' - 3409' 3590' - 3650' 3650' - 3710' 6297' - 6283' and 6022' - 5999' 5818' - 5798' and 5780' - 5766' 4927' - 4922'; 4911' - 4907'; 4889' - 4887'; 4883' - 4878'; 4870' - 4866'; 4853' - 4849' and 4843' - 4839' 4633' - 4618' and 4608' - 4604' 3268' ~WSO} SIDEWALL SAMPLES: See attached list. SQUEEZE JOBS: #1 - 168 cu. ft. Class "G" cement' through perforations at 3268'. PERFORATIONS OPEN TO PRODUCTION Four 1/2" jet holes per foot in the following intervals: *6297' - 6283'; *6022' - 5999'; 5919' - 5913'; 5830' 5780' - 5766'; 5714' - 5700'; 5684' - 5681'; 5672' 5582' - 5573'; 5455' - 5449'; 5422' - 5414'; 5400' 5345' - 5334'; 5296' - 5292'; 5270' - 5267'; 5240' 5228' - 5220'; 5196' - 5162'; 5126' - 5117'; 5115' 5072' - 5068'; 5052' - 5049'; 5036' - 5032'; 4927' 4889' - 4887'; 4883' - 4878'; 4870' - 4866'; 4853' 4816' - 4808'; 4778' - 4764'; 4752' - 4747'; 4720' 4633' - 4618'; 4608' - 4604'; 4571' - 4563'; 4551' 4530' - 4523'; 4521' - 4518'; 4492' - 4482'; 4446' 4400' - 4392'; 4328' - 4321'; 4290' - 4282'; 4276' 4235' - 4229'; 4206' - 4202'; 4152' - 4148'; 4143' 4089' - 4083'; 4074' - 4070'; 4064' - 4049'; 4002' 3956' -. 3951'; 3941' - 3939'; 3894' - 3890'; 3882' 3834' - 3830'; 3822' - 3818'; 3807' - 3792'; 3779' 3752' - 3742'; 3737' - 3732'; 3719' - 3715'; 3708' 3658' - 3642'; 3636' - 3624'; 3582' - 3572'; 3559' 3494' - 3487'; 3480' - 3469'; 3436' - 3428'; 3414' 3293' - 3278'. - 5822'; - 5663'; - 5380'; - 5237'; - 5112'' - 4922'; - 4849'; - 4714'; - 4545'; - 4435'; - 4266'; - 4139'; - 3984'; - 3877'; - 3774'; - 3688'; - 3552'; - 3362'; 5818' - 5798'; 5658' - 5648'; 5366' - 5358'; 5235' - 5232'; 5102' - 5090'; 4911' - 4907'; 4843' - 4839'; 5697' - 4679'; 4541' - 4538'; 4417' - 4413'; 4253' - 4243'; 4118' - 4116'; 3969' - 3965'; 3862' - 3842'; 3757' - 3755'; 3672' - 3662'; 3524' - 3502'; 3343' - 3326'; *Plugged off Completion Report Beluga River Unit 212-24 August 19, 1973 Commenced operations at 4 a.m., August 19, 1973. Drilled 17 1/2" hole to 371'. 74 pcf mud August 20-21, 1973 Drilled 17 1/2" hole to 430'. Opened hole to 26" to 430'. Ran 9 joints, 367 31' of 20" 949, H-40, buttress casing Cemented through duplex shoe Installed Gray Slip-on and Clamp well head with 20", 2000 psi top flange. 73 pcf mud '20" CASING DETAIL Description _Le ng_th Size Weight Grade Thread KB Depth Above KB - 2.31' 9 Joints 364.20 20" 94~ H-40 Buttress 361.89' Duplex Shoe 3.11 20" Buttress 365.00' On Hook 367.31' 20" CEMENTING DETAIL Cemented through shoe with 535 sacks of 100 pcf Class "G" cement premixed with 2.4% Gel by weight of water. Good returns throughout job. Cement returns to the surface. Started mixing cement at 4:14 a.m.; cement in place at 4:40 a.m., August 21, 1973. August 22-23, 1973 Installed Class II-B BOPE. Tested all kill lines and choke manifold to 3000 psi. Tested 20" Hydril and 20" CSO to 400 psi. Drilled 17 1/2" hole to 506'. 74 pcf mud Apgust 24, 1973 Drilled 17 1/2" hole to 980'. Pipe stuck at 927'. Formation took mud at 600 psi. Pumped in 60 barrels LCM pill and pressure increased to 1600 psi when pipe freed and circulation returned. Total of 160 barrels pumped to formation. Circulated and conditioned mud for five hours. Hole took 200+_ barrels fluid in the last two hours. Spotted 60 barrel LCM pill on bottom. Pulled out of hole. 70 pcf mud August 25-28, 1973 Drilled 17 1/2" hole to 3104' with full circulation. R~n. Schlumberger DIL log from 3104' to 365'. Drilled~ .~2~ "~ ~ August 29-30, 1973 Ran Schlumberger DIL log from 3204' to 3104'. Ran Schlumberger BHC Sonic and Density-Neutron Log from 3204' - 365'. Ran 77 joints, 3204.48' of 13 3/8", 68#, K-55, buttress casing. Cemented around shoe at 3202'. 72 pcf mud 13 3/8" CASING DETAIL Description L~e.ngth Si_z_e Weight Grade Threa~ Above KB 75 Joints 3115.48' 13 3/8'' Bottom 2 Joints incl. float collar and shoe 89.00' 13 3/8" On Hook 3204.48' 68# K-55 Buttress 68# K-55 Buttress KB Depth - 2.48' 3113.00' 3202.00' 13 3/8" CEMENTING DETAIL Stabbed into Baker 13 3/8" duplex shoe with 5" drill pipe. Cemented around shoe at 3202' with 1430 sacks of Class "G" cement premixed with 2.4% Gel by weight of water, followed by 830 sacks of Class "G" neat cement. Cement in place at 10:05 a.m., August 30, 1973. Good returns throughout job but no cement returns to surface. Cemented 13 3/8" x 20" annulus with 105 sacks of cement through a 1 1/4" pipe at 125'. Cement in place at 3:15 p.m., August 30, 1973. A~ust 31-September 1, 1973 Removed Class II-B BOPE and cut 20" casing. Installed 13 3/8" SOW x 12" 3000 psi Cameron casing head. Installed and tested Class III BOPE to 3000 psi. Raised mud to 77 pcf. 77 pcf mud September 2-4, 1973 Drilled out cement from 3105' through shoe at 3202'. Drilled 12 1/4" hole to 3840'. Cored the following intervals with an 8 15/32" core barrel: Core #1 3289' - 3349' No apparent dip, NOSFC. Interbedded sandstone, coal, siltstone. Core #2 3349' - 3409' Interbedded shale, siltstone, and sandstone. No apparent dip, NOSFC. Core #3 3590' - 3650' Interbedded shale, coal, siltstone, sandstone, and claystone. No apparent dip, NOSFC. Core #4 3650' - 3710' Interbedded sandstone, coal, and clay- stone. No apparent dip, NOSFC. Lost 50 barrels of mud to formation at 3777'. Reduced mud weight to 75 pcf. ' i'?~777 pcf 'mud 'q'~"[' ir~;~,*~ ?¢ h~ -,~ ,,-,, September 5-9, 1973 Drilled 12 1/4" hole to 6000'. Periodically circulated out gas. 76 pcf mud September 10-12, 1973 Ran Schlumberger DIL, Density Neutron, and Sonic logs from 6000' to 3202'. Ran Dipmeter and Proximity-Microlog from 6000' to 3002'. Drilled 12 1/4" hole to 6380'. 76-77 pcf mud September 13, 1973 Ran Schlumberger DIL log, Neutron-Density log, and Sonic log from 6380' - 5800'. Shot 23 sidewall samples, recovered 19. 76 pcf mud Sept~ember 14-15, 1973 Ran Schlumberger Proximity-Microlog from 6380' - 3202'. Ran 155 joints, 6379.51' of 9 5/8", 43.5#, P-110, S-95, and N-80, 8RD and buttress casing. Cemented around shoe and through float collar. Raised BOPE and installed 9 5/8" slips in 13 3/8" Cameron head. Cut 9 5/8" casing. Installed 3000 psi OCT tubing head and tested packing units to 3000 psi. Reinstalled Class III 12" - 3000 psi BOPE and tested to 3000 psi. 9 5/8" CASING DETAIL Description Length ~Ze ~ Grade Thread KB Depth Above KB - 3.52' Top 21 Joints 855.42' 9 5/8" 43.5# P-110 Buttress 851.90' Next 17 Joints 626,24' 9 5/8" 43.5# S-95 Buttress 1478.14' Next 42 Joints 1804.25' 9 5/8". 43.5# N-80 8rd 3282.39' Next 21 Joints 858.16' 9 5/8" 43.5# S-95 8rd 4140.55' Stage Collar 1.75' 9 5/8" 8rd 4142.30' Next 14 Joints 555.73' 9 5/8" 43.5# S-95 8rd 4698.03' Next 40 Joints 1677.97' 9 5/8" 43.5# P-110 8rd 6376.00' On Hook 6379.52' 9 5/8" CEMENTING DETAIL 1st Stage: Cemented around shoe at 6376' with 690 sacks of llSPcf Class "G" neat cement preceeded by 200 cu. ft. of water. Bumped plug on float collar at 6330' with 1800 psi. Good circulation throughout. Cement in place at 2:50 a.m., September 15, 1973. 2nd Stage: Cemented through stage collar with 630 sacks of 118 pcf Class "G" neat cement, preceeded by 100 cu. ft. of water. Closed collar with 2500 psi - held okay. Good circulation throughout job. Cement in place at 6:20 a.m., September 1~1~3~ -~ ~.~? r~' ii"i~i! ,%UL ! ': I 74 ~September 16-18, 1973 Drilled out stage collar at 4140'. Located plug on float collar at 6228'. Ran GO-International Gamma Ray-Neutron Log from 6 28' to 3000'. Ran Cement Bond Log from 6228' to 3000'. Shot four - 1/2" jet holes from 6297' - 6283' and 6022' - 5999'. Set packer at 5969' with tail to 5990'. Ran Formation Test #1 as follows: Formation Test #1, Interval 6297' - 6283' and 6022' - 599' Tool Assembly: Temperature recorder, 2 outside BT recorders, 8.7' of perforated tail pipe, RTTS packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hdro-spring tester, dual CIP valve, 95' heavweight drill pipe and backscuttling valve. Used no cushion. Packer set at 5969' with tail to 5990'. Open tool at 7:44 p.m. Light blow on bubble hose. Close tool at 8:01 p.m. for ICI. Open tool at 9 p.m. for FF. Light blow throughout. Close tool at 10:30 p.m. to start FSI. Opened backscuttle valve at 1:52 a.m. and pumped 80 barrels mud to equalize. Calc 1440+' rise in 5" heavy weight dp and 5" dp. Recovered 21+_ barrels fluid. Mud weight priot to test was 77 pcf. Three samples in rise and sample at tool are all 77 pcf and 56 gr/gallon. Depth Recorder ~Gauge I_~H I__F ISI ~ F.S! FH Top Inside 5955' 3186 136 2283 422 2846 3205 Bottom Inside 5959' 3184 142 2285 421 2844 3202 Top Outside 5985' 3224 156 Clock Stopped Bottom Outside 5989' 3214 169 2311 463 2866 3231 Bottom Hole Temperature: 108°F Set EZ drill permanent bridge plug at 5900'. Shot four - 1/2" jet holes per foot from 5818' - 5798' and 5780' - 5766'. Set packer at 5703' with tail to 5724'. Ran Formation Test #2 as follows: Formation Test #2, Interval 5818' - 5798' and 5780' - 5766' Tool Assemply: Temperature recorder, 2 outside BT recorders, 8.7' of perforated tail pipe, RTTS packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydro=spring tester, dual CIP valve, 95' heavyweight drill pipe and backscuttling valve. Used no cushion. Made formation test of the above intervals with packer set at 5703' with tail to 5724'. Opened tool at 5:24 p.m. ~or IF. Gas to surface in nine minutes. Vigorous blow to surface immediately. Attained a stable rate of 4.09 mmcf/day at 6:30 p.m. through a 1/2" choke. Surface pressure of 770 psi. Changed to 3/8" choke at 7 p.m. Stabilized by 8 p.m. at 1180 psi. Changed again to 1/4" choke. Stabilized at 1900 psi by 9 p.m. Rates, pressures, and temperatures are on accompanying chart. Two gas samples were taken at the conclusion of the test. Closedtoo~ ~:~ ~,. ~ ~i] l~i~t 05 .~. for FF. Released tool at 11:50 p.m. for a 165 minute FSI. ~, i ~ ~ -- Depth Recorder ~ ~IH_ I__~F F_~F FSI F_~H Top Inside 5690' 3084 263* 2022 2806 3049 Bottom Inside 5694' 3069 298* 2017 2801. 3045 Top Outside 5719' 3082 344* 2016 2804 3072 Bottom Outside 5723' 3107 300* 2021 2805 3074 *Questionable Maximum Bottom Hole Temperature: 100°F 77 pcf mud September 19, 1973 Set EZ drill bridge plug at 5755'. Shot four - 1/2" jet holes per foot in selected intervals from 4927' - 4839'. Set packer at 4798' with tail to 4819'. Ran Formation Test 93 as follows: Formation Test 93, Intervals 4927' - 4922'; 4911' - 4907'; 4889' - 4887'; 4883' - 4878'; 4870' - 4866'; 4853' - 4849' and 4843' - 4839' Tool Ass~mply: Temperature recorder, 2 outside BT recorders, 8.7' of perforated tail pipe, RTTS packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydro-spring tester, dual CIP va]He, 95' heavyweight drill pipe and backscuttling valve. Used no cushion. Made for~nat±on test of the above intervals with packer set at 4798' with tail to 4819'. Opened tool at 4:26 p.m. for IF. Gas to surface in three minutes. Strong blow to surface immediately. Used 5/8" downhole choke. Obtained stable rates and pressure with a 1/2", 3/8", 1/4" and 3/16 surface chokes. Choke Size Start Finish Stable Press [at head) 5/8" x 1/2" 4:26 4:55 1110 psi 5/8" x 3/8" 4:55 5:30 1310 psi 5/8" x 1/4" 5:30 6:10 1770 psi 5/8" x 3/16" 6:10 6:58 1895 psi Closed tool at 7 p.m. for FSI. Released tool at 9:20 p.m. for a 140 minute FSI. Depth Recorder Gauge ~I~H. _I? F_~F FSI FI__!{ Top Inside 4784' 2593 1022 1980 2183 2571 Bottom Inside 4788' 2584 1019 1973 2174 2581 Top Outside 4814' 2603 811 1977 2184 2587 Bottom Outside 4818' 2607 1075 1979 2180 2591 Maximum Bottom Hole Temperature: 95°F 77 pcf mud' September 20, 1973 Set EZ drill bridge plug at 4830'. Shot four - 1/2" jet.holes per foot from 4633' - 4618' and 4608' - 4604'. Set packer at 4549' with tail to 4570'. Ran Formation Test ~4 as follows: Formation Test 94, Interval 4633' - 4618' and.4608' - 4604' Tool Assembly: Temperature recorder, 2 outside BT recorders, 8.7' of perforated tail pipe, RTTS packer, VR safety joint, hydraulic jars, 2 inside BT-recorders, hydro-spring tester, dual CIP valve, 95' heavyweight drill pipe and backscuttling valve. Used no cushion. Made formation test of above intervals with packer and tail depths as indicated. Opened tool at 12:36 p.m. for IF. Gas to surface in ten minutes with strong blow. Used a 5/8" downhole choke with a 1/2" surface choke. Attained a stable rate in 37 minutes with 440 psi head pressure. With 3/8" surface choke took 44 minutes to stabilize at 665 psi surface pressure. With 1/4" choke took 54 minutes to settle at 1120 psi surface pressure. Closed tool in at 3:22 p.m. for FSI. Released tool at 5:53 p.m. for a 141 minute FSI. Depth Recorder Gauge IH IF FF FSI FH Top Inside 4536' 2554 46 1267 1963 2434 Bottom Inside 4540' 2473* 43 1258 1955 2445 Top Outside 4566' 2456 108 1267 1960 2441 Bottom Outside 4570' 2462 97 1269 1962 2441 *Questionable M~aximum Bottom Hole Temperature: 74°F Pulled test tools. Ran in with 8 5/8" bit; stopped at 4621'. 77 pcf mud September 21-23, 1973 Ran in with 8 1/2" impression block to 4621' - no impression. Swaged with an 8 1/2" swage through tight casing from 4621' to 4625'. Ran a 9 5/8", 43.5~ casing roller; ran very rough. Swaged with an 8 5/8" swage through tight casing from 4621' to 4626'; swage was worn to 8 3/8". Swaged again from 4621 to 4626' with an 8 5/8" swage; swage was worn to 8 3/8". Ran 8 5/8" casing roller; ran very rough from 4621' to 4623'. Swaged with 8 11/16" swage from 4621' to 4626'; swage was worn to 8 5/8". 77 pcf mud S~eP~tem~er 24, 1973 Ran 8 5/16" x 5' feeler to 4630' - okay. Set EZ drill bridge plug at 3300'. Shot four - 1/2" jet holes at 3268'. Set packer at 3205' with tail to 3226'. Ran a zonal segregation test as follows: ,Itel I" i9'/4 Formation Test #5, WSO at 3268' Tool Assembly: Temperature recorder, 2 outside BT recorders, 8.7' of perforated tail pipe, RTTS packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydro-spring tester, dual CIP valve, 95' heavyweight drill pipe and backscuttling valve. Use no cushion. Ran WSO through perforations at 3268'. Packer set at 3205 with tail to 3226'. Bridge plug at 3300'. Opened tool at 4:13 p.m. for flow period. Gas to surface in three minutes. Obtained a stable flow rate of 4.1 mmcf/ day through a 5/8" downhole choke and 3/8" surface choke. Closed tool at 5:16 p.m. for a 63 minute flow period. Released tool at 6:48 p.m. for a 92 minute final shut-in. Had maximum surface pressure of 1380 psi. Depth Recorder Gauge I._~H IF FF FSI FH Top Inside 3202' 1666 735* 1491' 1545 1666 Bottom Inside 3206' 1667 66* 1497' 1542 1667 Top Outside 3231' 1670 848 1495' 1534 1670 Bottom Outside 3236' 1683 859 1542 1544 1683 *Questionable Estimated Bottom t~le Temperature: 75°F Conclusion: WSO but gas not. 77 pcf mud September 25, 1973 Set packer-at 3100'. Obtained breakdown of holes at 3268' with 1400 psi. Squeezed 175 sacks of Class "G" cement at 20 cu. ft. per minute at 1900 psi. Closed tool on 70 cu. ft. of water and squeezed to a final pressure of 2100 psi in 1 hour and 45 minutes. Cement in place at 2:45 a.m., September 25, 1973. Eastimated 168 cu. ft. of cement out holes. Held pressure on holes until 5:00 a.m., September 25, 1973. Drilled out cement from 3146' to 3268'. 77 pcf mud s.eptem.b..erL ~2_6-~27, 1973 Ran Cement Bond Log from 3300' - 3150'. Drilled out EZ drill bridge plugs at 3297', 4829', and 5752'. Equalized 25 sacks of Class "G" cement through open end drill pipe at 5985'. Pulled to 5945' and reversed out excess cement. Cement in place at 1:20 a.m., September 27, 1973. Perforated four 1/2" jet holes per foot in seven runs in the following intervals: 5919' - 5913'; 5861' - 5854'; 5830' - 5822'; 5714' - 5700'; 5684' - 5681'; 5672' - 5663'; 5658' - 5648'; 5582' - 5573'; 5459' - 5455'; 5422' - 5414'; 5400' - 5380'; 5366' - 5358'; 5345' - 5334'; 5296' - 5292'; 5270' - 5267'; 5240' - 5237'; 5235' - 5232'; 5228' - 5220'; 5196' - 5162'. Ran in hole and circulated and c°nditi°ne~[-~u~ ~ F~:'~ ~ ~/~/ !'-~ ~-~~':~J~ I~~~ ~ ~ !~ cf mud ,.It!L !" September 28-29, 1973 Perforated four 1/2" jet holes per foot' in six runs in the following intervals: 5126' - 5117'; 5115' - 5112'; 5102' - 5090'; 5072' - 5068'; 5052' - 5049'; 5036' - 5032'; 4816' - 4808'; 4778' - 4764'; 4752' - 4747'; 4720' - 4714'; 4697' - 4679'; 4571' - 4563'; 4551' - 4545'; 4541' - 4538'; 4530' - 4523'; 4521' - 4518'; 4492' - 4482'; 4446' - 4435'; 4417' - 44].3'; and 4400' - 4392'. Ran in hole and circulated and conditioned mud. Perforated four 1/2" jet holes per foot in six runs in' the following intervals: 4328' - 4321'; 4290' - 4282'; 4276' - 4266'; 4253' - 4243'; 4235' - 4229'; 42Q6' - 4202'; 4152' - 4148'; 4143' - 4139'; 4118' - 4116'; 4089' - 4083'; 4074' - 4070'; 4064' - 4049'; 4002' - 3984'; 3969' - 3965'; 3956' - 3951'; 3941' - 3939'; 3894' - 3890'; 3882' - 3877'; 3862' - 3842'; 3834' - 3830'; 3822' - 3818'; 3807' - 3792'; 3779' - 3774'; and 3757' - 3755'. Ran in hole and circulated and conditioned mud. Perforated four 1/2" jet holes per foot in six runs in the following intervals: 3752' - 3742'; 3737' - 3732'; 3719' - 3715'; 3708' - 3688'; 3672' - 3662'; 3658' -3642'; 3636' - 3624'; 3582' - 3572'; 3559' - 3552'; 3524''- 3502'; 3494' - 3487'; 3480' - 3469'; 3436' - 3428'; 3414' - 3362'; 3343' - 3326'; and 3293' - 3278'. Ail perforations shot with GO-international centralized 28 gram Glass strip Jets. Scraped casing with two 9 5/8" casing scrapers to 5942'. 77 pcf mud September 30, 1973 Set Baker Model "D" packer on tubing at 5309'. 77 pcf mud October 1-3, 1973 Ran and hydrotested to 5000 psi, strings 1 and 2 of 2 7/8" tubing. Land string #1 at 5922' and string #2 at 3895' (see attached tubing list). 77 pcf mud October 4, 1973 Ran and landed 2 3/8" string #3 at 3258' and 2 1/16" string #4 at 2105' (see attached tubing list). October 5, 1973 Capped well with inverted 10" x 3000 psi casing head with 9 5/8" 8rd swage to 2" line pipe and 3O0O psi valve. Released crew at 10 1973, to wait on xmas tree. ,.i l !...!" :i: 74 October 6-20, 1973 Operations suspended until xmas tree arrived. October 21-23, 1973 Commenced operations at 12:01 a.m., October 21, 1973. Removed temporary flange from tubing head. Installed OCT xmas tree and tested to 3000 psi for ten minutes. Displaced down 9 5/8" annulus and up string #4 with 612~ cu. ft. of diesel, string #3 with 410+_ cu. ft. of diesel, string #1 with 700+ c. ft. of diesel, and string 92 with 335+ cu. ft. of diesel. Set Otis position #1 plug in "S" nipple at 4592'. Pressured to 3600 psi and set packers at 4584', 4173' , and 3916' . Pressure on tubing 3500+ psi with 350-400 psi on annulus. Opened XA sleeve at 4170'. Pumped in string #1 with 1600 psi; had 400 to 800 psi annulus pressure. Closed XA sleeve at 4170'. Pressured string #1 to 4600 psi with no' bleed off in pressure. Repressured to 4500 psi and still no bleed off. Opened XA sleeve at 4170'. Pumped down string #1 at 1750 psi and had a 400.~ increase in annulus pressure. Closed XA sleeve at 41~0' and pulled position #1 plug as 4592'. Installed Brown plug at 5323' in "D" nipple. Pumped down string #1, through open XA sleeve at 5304' with 9.5 cu. ft. per minute at 1500 psi. No change, in ~nnulus pressure. Closed XA sleeve at 5304' and opened XA sleeve at 4581'. Pumped down string ~1, through open XA sleeve, at 4581' with 9.3 cu. ft. per m±nute at 1600 psi. No change in annulus presaure. Closed XA sleeve, at 4581' and opened XA sleeve, at 4170'. Pumped down string ~1 through, open XA sleeve at 4170' with 9.5 cu. ft. per minute. Annulus pressure i.ncreased from 500 psi to 780 psi.. Closed XA sleeve at 4170' and opened XA sleeve at 3913'. Pumped down string ~1 through opened XA sleeve, at 39'13' with 9.5 cu. ft. per mi.nute. Annulus pressure increased from 480 psi to 850 psi. Closed XA sleeve, at 3R13'. Retri. eved Brown Plug at 5323' from stri.ng ~1. Set Brown plug in string ~2 ~n "D" nipple at 3552'. Pressured string #2 to 4300 psi. Packer set at 1500 psi. Bled down pressure and then pressured string #2 to 4600 psi and held for ten minutes with no bleed back. Pulled Brown plug at 3552'. Pumped down str±.ng .92 at 1180 ps~ with no increase in annulus pressure.. Set Brown plug in "D" nipple at 3248' in string #3. Pressured string #3 to 4400 psi. Packer set at 1200+ psi. Held pressure for 15 minutes. Bled annulus to 0 psi and pressure in string #3 to 600 psi. Repressured string #3 to 4600 psi and had no annulus pressure. Pulled Brown plug from "D" nipple at 3552' in string 93. Set Otis position #4 plug in string #2 at 96'. Set Otis position #2 plug in string #1 at 135'. Set Otis position #2 plug in string #3 at 128'. Secured xmas tree. Released rig at 4 p.m., October 23, 1973. Bruce B. Berget F.rm P-7 " ]e; OIL AND GAS CONSERVATION COMMITTI E~~,~ %. Am N'Ur~-~C~U~ CODS I '~"~'~~' 50-283-20037 ~ ' ........... : -- 6. L~SE D~IGN~ON ~D SER~L NO. : WELL cOMPLETION OR RE~OMPLETION REPORT la. TYPE OF WELL: OIL ~ u*S '~' ~ other WELl. WELL ~ DRY ~. TYPE Or CO~L~O~ .... [ '2"G~6L'~' WELI, OVER EX BACK nESVR. Other ..~ ~.-~. [ -- ~ ............... Beluga River S~andard Okl Company of California, ~0I ........................ ~" :- / ~ ..... ~t .... BRU 212-24 P O BOX 7-839 Anchorage, Alaska 99510 · · ,. 4. LOCa~mx 0~' WZLL (Report location clearl~ and ~n accordance with anp ~tate req~i~ e~m~: B e 1 U g a Ri v e r.~;, E ~ e 1 d itsu~ace 2000.46' South & 50.44' East of theg~rthW-est Corner of Sec. 24: T-13-N, R-10-W, SB&M At top ~roa. interval reported below S e same as surface ' R 10W SB & M At total Same as surface ,z. P~ITNO. . ~. 72-15 . . ,. , [i4. DXTE T.D. RF~UCHED IS. D~TE CO'MP SUSP, Oa'~BAND. ELEVA~ONS ,DF, RKB ~'r, GR, ~C)* 17. ~V. CASINGItEAD 8-19-73 [ 9-13-73 10-23-73 98' KB 77. 3' 1~. TOTAL DE.H, N~ & TVD~9. PLUG, ,BACK MD & ~D~. ~ ~LT~LE CO~L.. 21. INTERVALS DRILLED BY 6380 '-MD 63~ [5945. !MD 5945 'T'V~. ..HOW ~Y' aOTA~Y0__6380 'T°°LS [ ' CaS,,E TO0,.,S ~. PRODUCING !N~VAL(S, OF.~.IS CO~P~TIQN--TO~, BOSOM. NAME (~ AND ~)' ] 23. WAS D!REC~ONAL 8UR. VEY MADE Top 3278~D ~ TVD ~ ~'op 37BS~MD BottOm-~752~D ~ ~VD Bo~er 8torl~nq Bottom 5019~D . , i NO. 24. T~E E~CT~IC A~ND OTH~ LOGS RUN Loo- Dansltv-NeutrOn 'Depmete. r, ~roxlmlu3~M~uzulog, ~emen~ ~onaiog, ~amma Neutron ~og CAS~G R~RD (Report aH strings set in C~S~gG .S1ZE WE~G~ LB,'FT. DE~ SET (~)- ~OLE SIZE ! CEMLNT~NG RECO}~ I ~OUNT PULLED SEE ATTACH ~! I 26 LINER R~C OtqD TOP (~¢ID) 1~ OTTO~I (AID) . PER. FOR.AR'IONS OPFZN TO PRODUC~ S. oo attac-hmon%~ DF~//i INT~V.~ (MD~ .t' .--'FEB I 9 1974. --[ .. ., DA'r'~ FIRST PI%ODUC~OH [ ~ODUC~ION MEI-I~O:D iZlowh~a, gas liii,' pampk~g~size and type of 9ump~ Not produced[. . D~TZ OF T~ST, ~HOURS. TESTD.; .{[CI-t0:{E":: 'SIZE ' !T~RO~'}qES'I~?FOR CAk~G PRESSURE; mCAL~~ OI~EBL'. 27. TUBINO RE C OP~I) SEE ATIACHMENTm ~'~ mt ' 29. -ACID. SHOT. F;i~C5 O'RE. C~',IENT SQUEEZE, ETC. AM©UN£ ~'~D KIND OF MA1EP~AL US~ 168 Cu ft. of Class "G" neat cement squeezed in perforations at 3268'. [V¢'}:LL p'FATUS (Producing or I~'m~"n~shut in WA~DBL. [OIL GRAVITY-~I (CO~,) 1 , TEST WITNESSED BY S2. LIST O~' ATtaCHMeNTS Attac~ents. ~1-19,. Logs listed in line. 26, 33. I hereby c~q'tif]~ that the foreg0ily~'nd attached information i8 complete and correct as determined from all-available records ~ i ' i ~ *(See InstructiOns and S~ces for Additional Data on Reverse Side) iNSTRuCTioNS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showr~) for depth measure- ments given in cther spaces on this form and in any attachmer'~ts. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item '20, and in item 27 show the pl,.;Jucir~,g in'tcrval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produce,d, show- ing the ack. Jitional data pertinent to such interval. , 71~. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced, (See instruction for items 20 and 22 above). 34. SUMMAI{¥ ()F IoOI{.MATI()N 'I'ES'ii.,-; IN('I.LII)IN¢; INTI-HJV^I.., 'l'F,e,'l'l~ I). t'IIE.'.-;SI, rIIE I)ATA ~ JLE(,OVI.:I~IIES ()P {.)IL,. (.;AS. 35 (.; IgOI_~G 1 C M A R K lr2P~q WA'I'EI~ AND MUD ,,. , , Formation Test #1 5999' - 6022' & 6283' - 6297' (See attachment #4) .................. Formation Test ~2 5766 ' - ·5780 ' & 5798 ' 5818 ' ,:. - (See attachment ~ower. sterling Iormatlon #5) 3275' 3275' Formation Test #3 4839' - 4843'; 4849' - 4853' ~4866' - 4870'; Beluga River 4878' - 4883' ; 4887' - 4889'; 4907' - 4911' & 4922' - 4927' (See attachment 6) formation 3752' 3752' Formation Test #4 4604' - 4608' & 4618' - 4633' (See attachment 7 . Formation Test #5 3268' (See attachment 8) · , ' 3ti. ("ONE D^TA. ^',','^Cll. 'I}RI£E-DIgSt,C:.-i,kI.~j~']0N'$ 0~,"I~,-TAIOLOGY. POTIOSITY. FIIACTUIIES. ApPAR~N'~. Dii~S~ < A. ND} I.)~:I:EC,'.'I:F~) .'q!!OWS Ole. {.}IL.. GA.S Ol:t WA"I'E'It, Core #1 3289 ' - 3349' Interbedded sandstone, coal, siltstone, no a.Dparent din, NOSFC Core #2 3349' - 3409, Ynterbedded shale, siltstone and sandstone. .-' No apparent diD, NOSFC Core f3 3590' - 3650' Interbedded shale, coal, siltstone, sandston and claystone. No apparent dio~ NOSFC Core .~4 3650' - 3710' Interbedded sandstone, coal & claystone. No ~Darentee attadc~n~O~F~or further core data and sidewall samole data) ATTACHMENT #1 WELL COMPLETION REPORT BELUGA RIVER UNIT 212-24 ...... CASING RECORD . · CASING SIZE 30" 20" 13 3/8" 9 5/8" WEIGHT DEPTH SET LB/FT GRADE MD '~. 79' HOLE SIZE CEMENTING RECORD 30" Driven 94 H-40 365' 26" 68 K-55 ' 3,202' 6,376' 43.5 N-80 S-95 . P-Il0 535 sacks of Class "G" with 2.4% Gel 17 1/2" 1430 sacks of Class "G" with 2.4% Gel followed by 830 sacks neat Class "G" 105 sacks of neat ~lass "G" in annulus. 12 1/4" 690 sacks of neat .. Class "G" around shoe an 818 sacks of neat Class "G" through the stage collar. 'AMOUNT PULLED ,,, None None .. None None .. · FEB 1 9 ~974 DIVISION OF OIL ,~ND GAS ~T~TACHM~,NT #2 Comptetio'n Report ~ Wail # BRU 212-24 Sec. 24 T. Date 1./30,/74 13N String R. 10W #1 SB&M Description K.B. to tubing hanger Tubing hanger 1 joint Pup joint Pup joint Pup joint .._ Pup joint 3 joints Otis "S" Nipple(pos#2) 98 joints Otis "XA" Sleeve 1 joint Brown "CC"safety joint Pup joint Brown HS-17-3C packer 8 joints Brown straight pull safety joint 1 joint Otis "XA~ steeve Brown HS-17-2C packer Pup joint Pup joint 11 joints Brown straight pull safety joint P~D joint Pup joint Otis "XA" Sleeve , Brown H1- RSP packer XO top & bottom 3. 1/2" x 2 7/8" 8RD' Otis "S" nipple(Dos.#3 Pup joint Pup joint 6 joints Camco MMA Mandrel w/CEV 1 joint Length 20.70' .44' 30.82' 6.19' 8.02' 6..03' 2.09' 94.56' 1.56' 3027f89' 3'17'I 30.79' 1 43' 10i15' 5 98' 247.72' 2.47' 30.90' 3.19' 7.02' 6.00' 6.10' 347.80' 2.52' 6.12' 4.05' 3.19' 7.47' 1.57' 1.07' 2.197 185.72 12.8'3 31.02 Size 2 7/8" ~2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8 ". 2 7/8" 2 7/8" 2 7/8" ~2 7/8" 2 3/8" ~9 5/8" 2 7/8" 2 7/8" 2 . 7/8" 2 7/8" 2 7/8" · 2 7/8" ~9 5/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" ~9 5/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" Weight 6.5# 6.59 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# Grade N-80 N-80 N-80 'N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N- 8·0 N-80 N-80 N-S0I N-80 N-80 N-80 N-80 Thread EUE top & bottom E UE E UE E UE E UE E UE E UE EUE E UE E UE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EU E EU'E EU'E K. B. Depth 20.70' 21.14' 51.96' 58.15' 66.17' 72.20' 74'.29' 168.85' 170.4!' 3198.30' 3201.47' 3232.26' 3233.69' 3243.84' 3249.82' 3497.54' 3500.01' 3530.91' 3534.10' 3541.12' 3547.12' 3553.22' 3901.02' 3903.54' 3909.66' 3913.71' 3916.90' 3924.37' 3925.94' 3927.01' 39R9.20' 4114.92' 4127.75' 4158.77' Completion Report (contint% Well # BRU 212-24 string Sec. T. R. Date #1 SB&M Description Brown ~traigh't pull safety joint Pup joint Otis "XA" sleeve Brown H1-RSP packer XO top and bottom 3 1/2" x 2' 7/8" 8RD Otis "S" Nippl~ (pos#2) 11 joints Camco MMA mandrel W/CE 1 joint Brown Straight pull safety joint PuD joint Otis "XA" sleeve Brown 'H1-RSP p~ck~r XO Top and bottom -3 1/2" x 2 7/8" 8RD Otis "S" nipple (pos#l) Pup joint PuD joint Pup joint 21 joints Camco MMA Mandrel W/CEV 1 Joint Otis "XA" sleeve 3 1/2" 8RD PiN x 2 7/8" Box XO 3 1/2" Buttress Pin x 3 1/2" 8RD Box XO 3 1/2" ARMC0 SEAL LOC) PIN x 3 1/2" Buttress Box XO Stop sub Bake 4.750" Baker Seal Unit W/12' 'of seals and sto sub. 3 1/2" 'buttress Box x 3 1/2" ARMCO SEAL LOCK XO 2 7/8" EVE x 3 1/2" Buttress Pin XO Length 2.53' 9..15 ' 3.18' 7.47' 1.55' 341.45' 12.98' 31.31' 2.50' 10.03' 3.17' 7.47' 1.60' 8.13' 2.20' 4.09' 651.57' 12.93' 31.35' 3.12' .68' .55' .50' .72' r Model "D" 12.62' .40.' .56' Size 2 7/8" 2 7/8" 2 7/8" 2 7/8" 9 5/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 . 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" ~3 1/2" 3 1/2" 3 1/2" 3 1/2" ~acker 3 1/2" x9 5/8" 3 1/2" 2 7/8" x 3 1/2 Weight 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5~ ~t 5309 Grade N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 Thread E UE EUE E UE EUE EUE EUE EUE EUE EUE EU E EUE EU E EUE EUE EUE E UE EUE EUE EUE E UE EUE EUE x Buttress Buttress Seal loc Seal Lock Seal lock Seal x Buttres Buttress x EUE K. B. Depth 4161.30' 4170.45' 4173.63' 4181.10' 4182.65' 4524.10' 4537.0'8' 4568.39' 4570.89' 4580.92 ' 4584.09' 4591.56' 4593.16' 4601.29' 4603.49' 4607.58' 5259.15' 5272.08' 5303.43' 5306.55' 5307.23' 5307.78' 5308.28' 5309.00' 5321.62' 5322.02' 5322.58' Completion Report (~tin~ d) Well # BRU 212-24 String #1- Sec. T. R. Date SB&M in Length · size.-, W. eight Grade, Thread K.B. Depth ipple .94' 2 7/8" EUE 5323.52' bottom 598.66' [ 2 7/8" 6.5# N-80 EUE 59'22.18' t 45© and ~ _ . · I . · · Descripti¢ Camco "D" 19 joints ( joint cut rounded) Completion Report Well # BRU 212-24 Sec. T. Date Tubing Detail R. String SB&M Description K,B. to tubing hanger Tubing hanger 1 joint Pup joint Pup joint 2 joints Otis "S" Nipple (pos. #4) 100 joints Pup joint Pup joint Pup joint Otis "XA" sleeve Pup joint Pup joint Brown HS-17-3C packer Brown adjustible Union Pup joint Pup joint Pup joint Pup joint Pup joint 8 joints Otis "XA" sliding sleeve Pup ~joint Pup joint Brown straight pull safety joint Pup joint , Pup joint Brown HS-17-2C packer · Brown adjustible Pup joint Camco "D" nipple 11 joints venturi shoe union .Le~ngth_ _, 2.0.70' .44' 30.77' 8.14' 7.99' 62.59' 1.57' ~3066.28' 6.10' 7.99' 7.94' 3.18' 10.05' i0.10' 5.982 5.61 4.04' 2.16' 2.12' 2.15' 2.19' 2~4.92' 3.18' 6.11' 4.05' 2.5~' 1.11' 4.12' 7,02 2.14 8.00' .95' 342.41" .66' Size 2 7/8 2 7/8 2 7/8 2 7/8 2 7/8 2 7/8 W ei_g ht ,. II " 6.5# " 6.5# " 6.5# " 6.5# 2 7/8" 2 7/8" 6.5# 2 7/8" 6.5# 2 7/8" 6.5# 2 7/8" 6.5# 2 7/8" 2 7/8" 6.5# 2 7/8" 6..5.~ 2 7/8- X2 7/8" X2 3/8" X9 5/8" 2 7/8'! · 2 7/8" 6.5~ 2 7/8" 6.5# 2 7/8" 6 . 5# 2 7/8" 6 . 5~ 2 7/8" 6 , 5# 2 7/8" 6.5~ 2 7/8" 2 7/8" 6.5~, 2 7/8" 6.5# 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" ~9 5/8". 2 7/8" 2 7/8" 2 7/8" 2 7/8, 2 7/8" 6.59 6.5# 6.5# 6.5# Grade N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-,BO N-80 N-80 N~80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 Thread EUE E UE ~UE EUE E UE EUE E UE E UE EUE E UE E UE EUE E UE E UE E UE E UE E UE E UE E UE E UE E UE E UE E'UE E UE E UE E UE E 'UE E UE EUE E UE E UE E, UE K. B. Depth 20.=70' 21.14' 51.91' 60.05' 68.04' 130.63' 132.20' 3198.48' 3204.58' 3212.57' 3220.51' 3223.69' 3233.7d' ~gA~ ~A~ ~3249.82 3255.43' 3259.47' 3261.63' 3263.75' 3265.90' 3268.09' 3513.01' 3516.19' 3522.30' 3526.35' 3528.87' 3529.98' 3534.10' 3541,12 3543.26' 3551.26' 3552,21' 3B94.62' 3895.28' Completion Repert Well f/ BRU 212-24 Sec. T. Date Tubing Detail R. String SB&M #3 Description D.B to~ tubing hanger Tubing hanger 1 joint Pup joint Pup joint- 2 joints Otis "S" ' '~ ~ nipple (pos.#2) 99 joints Otis "XA" sleeve 1 joint Brown J latch st.ing~r Brown HS-17-3C packer Camco "D" nipple Pup joint Venturi Shoe Len_f~th 20.70' .44' 30~10' 10.08' .6.20' 60.59' 1.51' 3077.81' 2.87' 31.84' 1.70' 5.98' .91' 7.99' .57' Size 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 7/8" ~2 7/8" ~2 3/8" ~9 5/8" 2 3/8 2 3/8" 2 3/8" Weight. 4.7# 4.7# 4.7# 4.7# 4.7# 4.7# Grade N-80 N-80 N-80 N-80 N-80 N-80 N-80 Thread K.B. Depth EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE F, UE 20.70' 21.14' 51.24' 61.32' 67.52' 128.11' 129;62' 3207.43' 3210. 30 ' 3242.14' 3243.84' 3249.82 ' '3250.o65' 3258.64' 3259.21' Completion Report Well # BRU 212-24 Sec, T, Date X~ Tubing Detail SB&M String #4 Description K. B.' to tubing hanger Tubing hanger 8 Joints Otis "N" nipple 60 joints Length 20.70' .-44 ' 245.46 1.63 1836.'32 Size 1/16" 1/16" 1/16" 1/16" Weight 3.4# 3.4# Grade N-80 N-80 Thread K.B. Depth 10 RD 10 RD 10 RD 10 RD 20.70' 21.14' 266.60' 268.23' .2104.55' ATTACHMENT #3 5228' J'-~-~20% 5072' - 5068 4889' - 4887 4816' - 4808 4633' - 4618 '45.30' ~..452~3~' PERFORATIONS OPEN TO PRODUCTION - . . / ~' . . . .. ,; · . . / Four - 1/2" jet- holes' per foot.-.%n the following intervals: · 6297' -6283'; *6022' - 5999~'--_LJ 5919' - 5913'; 5830' - 5822'; 5818' - 5798'- 5780' - 5766'; 5714' - 5700'; 5684' - 5'681'-, 5672' - 5663'-, 5658' - 5648'-, 545~ - 5449'-; 5422' - 5-414'-, 5400' - 5380'-, 5366' - 5358'; 5296' - 52.92',- 5270' - 5267'; 5240' - 5237' ; 5235' - 5232'-, . 5196' - 5162'; 512,6_L~ 5117'' 5115' - 5112'; 5102' - 5090'' 5052' - 50'49'j ~5~36' - '"5~',*~' 4927' - 4922'; 4911' - 4907'; 4883' - 4878'; 4870' - 4866'; 4853' - 4849'; 4843' - 4839'', 4778' - 4764'; 4752' - 4747'-, 4720' - 4714'; 5697' - 4679'; 4608' - 4604'; 4571' - 4563'; 4551' - 4545'-, 4541' - 4538'; 4521' - 451.8'; 4492' - 4482'-, 4446' - 4435'; 4417' - 4413'', 4290' - 4282'; 4276' - 4266'; 4253' - 4243'; 4235' - 4229'; 4089' - 408'3'; 3956' - 3951'; 3834' w 3830'; 3752' - 3742'; 3658~ - 3642'; 3494' - 3487'; 3293: - 4206~. - 4202'; 4152' - 4148'; 4143' - 4139'; 4118' - 4116'; 4074~ - 4070-'.; 4064' - 4049'; 4002' - 3984'; 3969' - 3965';~- 3941' - 3939'; 3894' w. 3890'; 3882' - 3877'; 3862' - 3842'; 3822" - 3818'; 3807' - 3792'; 3779' - 3774'; 3757' - 3755'; 3737' ..... 3732'; 3719' - 3715'; 3708' - 3688'; 3672' - 3662'; 3636' - 3624'; 3582' - 3572'; 3559' - 3552'; 3524' - 3502'; 3480' - 3469'; 3436' - 3428'; 3414' - 3362'; 3343' - 3326'; * Plugged off Formatt~n Testing Service ~port DUNCAN, OKLAHOMA Ticket FLU I D SAM P LE DATA Date 9-18-73 Number 308475 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WA.LL District A-'NC~ORJ~GE cc. Oil C. BOATMAN cc. Water Tester Ho MANN Witness BILL SAVER cc. Mud Drilling Tot. Liquid cc. Contractor R.B. MONTGOMERY SM S Gravity. o APl @ OF. E Q U I PM E N T & H 0 L E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested. - Elevation 851 Kelly bushing 105 Ft. RESISTIVITY CHLORIDE Net Productive Interval 284' Ft. CONTENT All Depths Measured From Kelly bushing Recovery Water __ @ . °F. ppm Total Depth 6380' Ft. Recovery Mud __ @ __ °F. ::;- Main Hole/Casing Size 9 5/8" 43,5~ . .., Recovery Mud Filtrate @ °F. ":~'-.ppm Drill Collar Length - I.D. ',;i' Mud Pit Sample __ @ ~: °F. Drill Pipe Length 5977 ! i.D... 4,276" Mud Pit Sample Filtrate @ -'~F 5969' ~ ,~:!!:~ . .~ ppm Packer Depth(s) Mud Weight l0.3 vis cp Depth Tester Valve 595 ! I Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke .' Recovered 1447 Feeto, mu4-dY water - 20.73 bblso Recovered , Feet of Recovered Feet of O Recovered Feetof RecoVered Feet of Remarks Tool opened for 16 minute first flow with a light blow on bubble hose, Closed tool for 59 minute first closed in pressure period. Tool reopened for secohd flow with a light blow on bubble hose with 8 PSI surface pressure on 1/4" bubble hose, Closed for 265 minute second CIP period, Perforations 6283-6297' 5999.- 6022' Reversed out 26,73 bbls formation Gauge No. 3647 Gauge No. 3646 Gouge'No.3637 water. TEMPERATURE TIME Depth: 5955 Ft. Depth: 5959 Ft. Depth: 5985 Ft. 12 HourClock 24 HourCIock 12 HourClock Tool 9-17 A.M. , Est. °F~ Blanked Off no BlankedOff no Blanked o~es Opened 1944 P.M. 5991' Tool 9-18 A.M. ~ Actual 107°F. Pressures PreSSures Pressures Closed 0254 P.M. Field Office Field Office Field Office Reoorted Computed · J Initial Hydrostatic 3207 3186 3198 3184 3212 3224 Minutes Minutes ~ Initial 124 136 140 142 154 156 ~ o Flow -- -~. Final 177 178 175 182 171 195 17 16 Closed in 2295 2283 2271 2285 CS CS 59 59 ~ Initial 212 230 227 234 CS CS --- c o Flow ~"- - 8'c Final 406 422 402 421 CS CS 90 90 ~ Closed in 2839 2846 2848 2844 CS CS 264 265 · : a~ Initial ~ o Flow ...... ~. Final Closed in -'Final Hydrostatic 3189 3205 319~ 3202 3212 3242 -- CS = cl(ick stoppe(i ..... , , 'FLU I D SAMPLE DATA Ticket Date 9-18-73 Number 308475 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery:. Cu? Ft. Gas of Job HOOK ~ALL District ANCHORAGE. cc. Oil Co BOATMAN CC. Water Tester He Jv[~ Witness BTLL SAV~ cc. Mud Drilling Tot. Liquid cc. Contractor R. ~. MONTGC~ER¥ J~[ S Gravity. ° APl @ °F. EQ U I PM E N T & H O L E DA TA " Gas/Oil Ratio cu. ft./bbl. Formation Tested Elevation_ Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT All Depths Measured From ,,. Recovery Water ~ @ ~ 'F. ppm TOtal Depth Ft. Recovery Mud ~. @ ~ °F. Main Hole/Casing Size,,. Recovery Mud FiltJ/,-e .~ @ ~ °F. ppm Drill Collar Length.:', I.D. Mud Pit Sample ~ @ __ °F. ' Drill Pipe Le.0gth I.D M"dcl Pit.,Sample Filtrate @ °F. ppm Packer Depth(s), ~;,.: Ft. Mud WC~ight vis .cp Depth Tester Valv'e:" Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recover¢~d Feet of ,.. n Recovered Feet of Recovered Feet of r Recovered Feet of_ Recovered Feet of Remarks Fourth gauge · .,. Gouge No. 363~ Gauge No. Gauge No. TEMPERATURE TIME ,., Depth: . ......5989 Ft. Depth: Ft. Depth: Ft. 24 Hour Clock Hour Clock Hour Clock Tool Est. °F. Blanked Off yes Blanl~e'd Off Blanked Off Opened P.M. Tool .. Actual °F. Pressures Pressures Pressures Closed P.M, Field Office Field Office Field Office Reported Computed Initial Hydrostatic , 3245' 3214 Minutes Minutes ]=~ Flow-, Initial 166 169 I" Final 184 208 I Closed in 2311 2311 _ ., ~-o Initial 239 263 c o Flow ~ ~ 'Final 460 463 _ ~" Closed in 2861 2866 " in;rial ~ o FI0w ................ ~.. Final Closed in _Final Hydrostatic 3227 ____32_31 ...... PRINTED IN U.I.k. ~.: Gauge No. 364? Depth aock 609 hou j 308 ? First F irst:q;:'~Yi Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Temp. Log Temp. Temp. Log Temp. Temp. Temp. .000" Corr. .000" ~ Corr. .000" Corr. ~ .000" ~ Corr. .000" Corr. .000", f/ Corr. 0 ". 0000 136 .0000 ':'~-78 .GO00 230 .0000 42:1 ~ .0273' 141 .0342~'* ;~.-.408 .1022 279 .0891*~r* 1147 2 .0477 143 .0753 740 .2044 309 .2125 1818 3 .0681 159 .1164 958 .3066 323 °3359 2129 4 .0886 163 .1575 1313 .4088 375 ' .4593 2330 5 .1090 178 .1986 1593 .5110 40.1 '.5827 2455 6 .2397 1792 .6130 422 .7061 2~46 7 .2808 1956 .~: .8295 2605 8 .3219 2093 .9529 2665 9 .3630 2201 1.0763 2712 ]0 .4040 2283 1. 1997 2756 ]1 1.3231 2793 12 1.4465 2800 13 I 1.5699 2819 141 1~6933 28~3 ]5 ~ 1 .B16D 2846 , Gauge No. 3646 Depth 5959' Clock No. ' 8739 24 hour ~;.:~? 0.0000 142 0000 J. 182 0000 234 0000 421 ?l .0138~ 1 42 ,0168~* '~!~!i.t 413 .0508 280 .0439-~* 1181 2 .0241 147 .0369 .... =:'~- 762 .1016 308 o 1046 1840 3 ,03441 159 .0570 1040 .1524 325 o1653 2140 4 .0447! 164 .0771 1337 .2032 _ 381 .2260 2344 5 .05501 182 .0972 :-~.6,,22 · 2_:540 402 .2867 2463 ~.. 6 I .1173 ~8.12 .3050 421 .3474 2547 7 - 1374 ,~i?1965 .4081 2605 8 .1575 2091__ ,4688 2664 9 .1776 2194 .5295 2713 ]0 .1980 2285 .5902 2754 ] ] ,6509 2792 12 ,7116 2799 :~. 13 7723 2816 ~4 .8330 2830 · 15 . Rq&.O Reading Interval 3 6 : 15 18 Minutes REMARKS: *First interval is eaual to 4 m~nutmm. 9*5 m~_nutms. ~w¢*13 m~nutmm~ , '"'"'"'" '" "'""' SPECIAL PRESSURE DATA I 1`? Gauge No. 3637 ! Flow Period Time Deft. I PSIG Time Deft. I Temp. .000" Corr. .000°' I Depth · First Closed In Presi~bre Logz PSIG Temp. Corr. 5985' Second Flow Period Time Deft. .000" PSIG Temp. Corr. Clock No. 4485 Second Closed In Pressure Time Dell. .000" t+0 Log-~ PSIG Temp. Corr. I Ticket 12 hour No. Third Flow Period Time Defl. .000" PSIG Temp. Corr. 308475 Third Closed In Pressure Time Deft. Log-~ .000" PSIG TemD. Corr. 0000I 156 i0270-I 151 O4731 161 · 10 80 NolLe recor(Led' None 'ecorded recordl -- .ock sro~ ~ped cloc! · stoppe Non~ .ock sto :d )ped Gauge No. 0 14 15 0000 169 I 0236 1173 0338 I 1 86' .0439 1191 3636 Depth ,0540 208 Reading Interval o0000 .0167'~ .0367 .0567 .0767 .0967 .1167 .1367 .1567 oi767 ,1970 2O8 430 755 ~71 1342 1626 1817 1982 21t8 ___2223 2311 · .,~.989 ' .0000 ,0502 ,1004 ,1506 .2008 .2510 .3010 263 ,312 343 36§ . 425 443 463, Clock No. ,0000/ · 0436~** ,10401 .16441 .2248 ·2852 .3456 .4060 .5268 =6476 : 708.0_ .7RRA 08890 ,O'tl 2~ hour 463 1202 1855 2154 2353 2482 2573 2630 2689 2733 2775 2813 ,28/3 2837 285O 9RRR · 3 6 , 18 REMARKS: *First interval i~ e.~ua1 to 4 minutes. **5 minutes *~%= 13 minutes· M inures .... ,.,,,,,u.,.,,. SPECIAL PRESSURE DATA "'""'"' Reversing Su5 ............. Water Cushion Valve .......... Drill Pipe ...................... Drill Collars ...................... Handling Sub & Choke Assembly ..... Dual CIP Valve ................... Dual CIP Sampler ............... Hydro-Spring Tester ............... Multiple ClP Sampler ............... Extension Joint .................. AP Running<Case .................. Hydraulic Jar ............. VR Safety Joint ........... Pressure Equalizing Crossover ......... Packer Assembly . . . RTTS ........... Distributor ....................... Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ......... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly . Packer Assembly ................... Anchor Pipe Safety Joint ........... Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor ................. BT case Blanked-Off B.T. Running Case ....... Ht-500 I;D. 6.12" 3" 5" 4.276" 5" . 87" 5" 1" 5" '~'::"~ 75" 5" 3.75" 5' ~"~ .87" 5" 1" 8.10" 1,62" 2.88" 3.88" 3.88" 2.259" 308475 1I 5977' 5.41' 5.02' 4 · 04 ' 4.04' 5.07' 3.48' 4.64' .. 8.65' 4105' 4.10' 1.08' DEPTH 5845' 5951' 5955' 5959' 5969' 5985' 5989' 5991' OF4 ---~ Theoretical Open Flow Potential Ps P F P o, Q Q, Q~ R rw t to ~T Z ',~iLog -- Common Log With/Damage --' Extrapolated Static Pressure ............................... Psig. ~_~ Final Flow Pressure Psig. ~ Potentiometric Surface (Fresh Water*) ...................... Feet --- Average Adjusted Production Rate During Test ................ bbls/day ~ Theoretical Production w/Damage Removed .................. bbls/day ---Measured Gas Production Rate .......... · .................. MCF/D -. ., -- Corrected Recovery . . . bbls ~-- Radius of Well Bore . . Feet ~ Flow, Time ............................................. Minutes ~--- Total Flo, i~ Time ................ :. ...................... MinuS, es -- Temperature Rankine ~: .eR ~ Compressibility Factor .................................. i'~ -- Viscosity Gas or Liquid ................................... CP * Potentiometric Surface Reference to Rotary Table When Elevation Not Given, Fresh Water Corrected to I00° F. Each Horizontal Line Equal to 1000 p.s.i. Format!~on Testing'Service 'Relo'ort ~'~ FEB 1_ 9 ~974 HAI l IB IIII IZIIV SEII VIC ES DUNCAN, OKLAHOMA Ticket FLUID SAMPLE DATA Dote 9-18-73 Number 251586 '?~_ Sampler Pressure, P.S.I.G. at Surface Kind i I~olliburton Recovery: Cu. Ft. Gas of Job HOOK WALT. District ANCHORAGE cc. Oil cc. Water Tester MR. BOATMAN Witness MR. SAUER -- o ~oo cc. Mud Drilling -~' O Tot. Liquid cc. Contractor R, B, MONTGOI~R¥ DR S '.Gravity. ° APl @ °F. E q U I P M E N T & H 0 L E D A T A Lo Gas/Oil Ratio cu. ft./bbl. Formation Tested Beluga ~-~o Elevation 105 t KB Ft. ~t~ RESISTIVITY CHLORIDE Net Productive Interval, 37 ' Ft. · CONTENT All Depths Measured From Kelly Bushing o Recovery Water ~ @ __ °F. ppm Total Depth .5990' I~BD Ft. Recovery Mud __ @ __ °F. Main Hole/Casing Size__ 9 5/8" 43.5 · Recovery Mud Filtrate ____ @ __ OF. p:..%_m Drill Collar Length - I.D - C. 5679 I Mud Drill I.D Z~276" Pit Sample ~ @ -~':TF. Pipe Length ~: .... Mud Pit Sample Filtrate ~ @ :;F. ~. · ppm Facker Depth(s) 5703 t Ft. r-~ Mud Weight vis cp Depth Tester Valve 5685 ~ Ft. TYPE AMOUNT Depth Back Surface Bottom O Cushion Ft. 'Pres. Valve 5600' Choke 1/2-3/8-1/4 Choke 5/8" Recovered Feet of ~ ~ Recovered ;, Feet of ~ Recovered Feet of ~ Recovered Feet of Recovered Feet of Remarks Opened tool for 222,minute flow with a strong blow. Closed tool for 168 minute final closed in pressure. <:. Gauge No. 3636 Gauge No. 3637 Gauge No. 3646 TEmPERATUrE T~M~ Depth: 5690 Ft. Depth: 5694 Ft., Depth: ~719 Ft. 48 Hour Clock . 24 Hour Clock 12Hour Clock Tool 9- 18-7.8. M. Est. °F. BlankedOff No Blanked Off No BlankedOff Ye8 Opened 5:24 P.M. 5724' Tool 9-18-7~.M. Actuol l00? °F. .... ? Pressures J Pre]su,es Preiures Closed 9:05 P.M.Rel~orted Computed _ , Field Office Field Office Field _ Office initial Hydrostatic 3099 3084 3074 3069 '~093 3082 Minutes Minutes____ -- · ~ Flow Initial 221___ 263Q_ . 223 298Q ).27 344q >_.~ Final 2037 2022 2007 2017 ~991 2016 221 222 "Z -- Closed in 2806 280-6 "' 2799 2801 !795 2804 r' ---~5 168 ~o~ Initial c o Flow : ~°'c Final Closed in .__ Initial ~ o FI0w -- __ F na' .... Closed in Final. Hydrostatic 3062 3049'' 3022- 3045 3075 3072 Q-Qu, stionabl( , , , ~/'hPlk/I6Tl/'hlkl TI'qT. RATA Ticket F L U I D S A M P L E D A T A Date 9-18-73 Number 251586 Sampler Pressure ,P.S.I.G. at Surface Kind Halliburton of Job HOOK WALL District A~1CHORAGE Recovery: Cu. Ft. Gas cc. Oil cc. Water Tester ~. BOAT~&N Witness I"IR. SAUER cc. Mud Drilling Tot. Liquid cc. Contractor R. B. MONTGOMERY DR S Gravity. ° APl @ °F. E(p U I PM E N T & H 0 L E D~A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested Elevation Ft. RESISTIVITY CHLORIDE Net Productive interval Ft. CONTENT All Depths Measured From Recovery Water ~ @ ~ °F. .ppm Total Depth Ft. Recovery Mud @ ~ °F. Main Hole/Casing Size Recovery Mud Filtrate ?: @ ~ °F. ppm Drill Collar Length · .. i.D. Mud Pit Sample @ °F. Drill Pipe Length I.D Mud Pit Sample Filtrate ' @ __ °F.. ppm Packer Depth(s). Ft. Mud Weight vis ,cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke . ..: Recovered Feet of ..~ .,. Recovered Feet of Recovered Feet of . ,~,, Recovered Feet of _ Recovered Feet of Remarks [GaugeNo. 3647 GaugeNo. GaugeNo. TEMPERATURE TIME O,?th: ~ 7 23 ' Ft. Depth: Ft. Depth: Ft. ~__~ . -tour Clock Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Off Yes Blanl~ed Off Blanked Off Oper~ed P.M. Tool A.M. Actual °F. Pressures Pressures Pressures 'i Closed P.M. Repotted Computed Field Office Field Office Field Office Initial Hydrostatic 308/+ 3107 Mim~tes Minutes ..... -- ~'~ Flow In---~itial 230 3000_~_ _ ~. Final 2016 2021 Closed in 27 86 2805 ~ Initial c o Flow " '-- - -- 8'c Final Closed in Initial ~ o FI0w ~_~ Final ..... Closed in Final Hydrostatic 3067 3074.____ , , I Cosing perfs. 5766''5818t Bottom choke 3/8" Surf. temp °F Ticket 1'4o. 251586 Gas gravity. Oil gravity. GOR Spec. gravity. ,Chlorides ppm Res. @ °F Dote Choke Surface Gas Liquid Time a.m. Size Pre~ure Rate Rate Remcnr~ psi MCI: BPD 5:24 6:53 1/2 780 Changed to 3/8" choke 8:00 3/8 1180 Changed to 116" chotoe 9:05 1/4 1910 Closed £n and rewer~ed .~. 11: 50 ~'~:::~.,..::.. Pulled loose .. ; · , ~ · · ,~- ..... ,. Gauge No, 3636 First Flow Period Depth 5690' C~ock No. 7031 ITicket 24 hour No. (.312 ·3541 .4787 .6033 Time Dell. .000" .000 PSiG Temp. Corr. 263 ?Q First Closed In Pressure Time Deft. .000" t og~ PSIG Temp. Corr. .000 2022 .1049 764* 2557 .2295 974 984c) 1191 1318 !324C) 1852 .7280 2022 Gq,uge No. ¢I .0001 ,"1i .0532] 2J .1164J 967 .0396 ,0792 ..... 1188 ,1584 ,1980 · 2376 , , 2772 , ,3168 ., ,3564 .,3960 ,..435_6 _. 4752 · 5148 _45555 298q 755* 2641 2696 Z7~5 2,782 2795 2800 2802 .. 2804_ 2806 ~, 2806-- ___2806 2806 3637 Depth. .000 .0199 .0398 2017 2558 2643 Second Flow Period Time Defl. .000" PSIG Temp. Corr. 5794' Time Deft. .000" Second ClOsed In Pressure · ,. J bo. Z Clock No. 929f PSiG Temp. COrr. Third Flow Period Time Defl. -:~00" PSIG Temp. Corr. hour 48 251586 Third Closed In Pressure Time Deft. Log-~ .000" PSIG TemD. Corr. i 'l (. 1581 '4 .1796j · 2428j (.264 .30601 8,' .3690 978C) ' 1180 1309 i326C) 1842 2017 0597 0796 0995 1194 1393 1592 Recding Interval 38 ,1791 ,1990 ,2189 .2388 .2587 .2790 12 2691 2751 2778 2790 2796 2797 2799 2801 2801 2801 2801 2801 Minutes REMARKS: * First interval equal to 32 minutes q,-0uest ionable C-Choke change SPECIAL PRESSURE DATA ""'"" 5 6 7 lo '11 Gauge No. .. 3646 Depth First Flow Period Time Deft. .000" .000 · 2149 .4701 PSIG Temp. Corr. ,344q 757* 967 (., 640 · 7253 · 9805 (1,061 1. 2357 1,4910 I 988c) iI9I 1315 1330C 1843 2016 Time Deft. .000" 000 0809 · 1618 2427 .3236 ,4045 !.4654 ~_5663 ,6472 ..7281 · 8090 · 8899 .9708 1,0517 1. 1330 First Closed In Pressure PSIG Temp. Corr. 2016 2554 2638 2692 2750 5719' Second Flow Period Time Deft. .000" Gouge No. PSIG Temp. Corr. ¢i' 000 1064 2 .2327 3t(.316 --~t. 3590 5/.4853 /(.525 7J,'6116 81.7380 3OOQ 769, Clock No. 4609 Second Closed In Pressure Time Defl. .000" 2778 . 2790 2795 2797 2799 2801 2802 2804 2804 2804 3647 Depth 5723 .000 .0403 2021 2561 986 .0806 2642 .1209 2696 998C) 1199 2756 · 1612 1323 · 2015 2784 PSIG ·Temp. Corr. Ticket hour No. Third Flow Period Time Defl. .000" 1339C' 1848 2021 12! , · 2418 ,2821 ,3224 ,3627, 4030_ · 4433 ,4836 · 5239 ,5640 '14j Reading Interval 38 PSIG Temp. Corr. Clock No. 8739 hour 24 2795 2798 2800 251586 Third Closed In Pressure Time Deft. Lo- t + g7 .000" 9 T Prig Temp. Corr. 2802 '" 2804 2805 2805 12 2805 2805 Minutes REMARKS: f~ Firs: interval.~qual:.o_3.2mlnutes ....... O-.Oue~:ionable'. 2CzChoke change .. SPECIAL PRESSURE DATA ./ Reversing Sub ................. Water CUshion Valve - ' Drill Pipe ....................... Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Zester ................ Multiple CIP Sampler ............... ~,~e~e~c~-J~ -AP. Case ........... AP Running Case ...... ~ ......... Hydraulic Jar .-,~ ..... -,: ....... VR Safety Joint ....... Pressure' Equalizing Crossover ........ Packer Assembly ................... Distributor .................. . .... Packer Assembly ................... 6.12" 5" 5.00" 5.00" 3.00" 4. 276" .87" 1.00" 3,75" 3.75" 5,00" 5 00" 5.00" 5.00" 8.10" .87" 1.00" 1.62" Flush Joint Anchor ................ Pressure Equalizing Tube ........ Blanked-Off B.T. Running Case ....... Drill Collars ..................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Packer Assembly ................... Anchor Pipe safety Joint ........ Side Wall Anchor .................. Drill Collars 2.88" F, th. o n CehOr ................. ' 3.88" Blanked-Off B'THRIJn~J°~]'/'bUD Case ....... 3.88" 3.88" 22.59" LEN~FH DEPTH 5679' 5.41' 5.02' 4.04' 4.04' 07 ' 5685' 3,48' 4,64' 5690' 5694' 5703' __8~_65 4.05' -4.. lOt 1.08' 5719' --57-2-3.' 572.4' OF4 ~ Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D Ps -- Extrapolated Static Pressure ............................... Psig. P F -- Final Flow Pressure ....................................... Psig. Pot -- Potentiometric Surface (Fresh Water * ) ...................... Feet Q -- Average Adjusted Production Rate During Test ................ bbls/day Q, _-- Theoretical PrOduction w/Damage Removed .................. bbls/day Q g --Measured Gas Production Rate ............................ MCF/D R _-- Corrected Recovery ...................................... bbls r,~ _-- Radius of Well Bore .................. ?~..~. ................ Feet t --- Flow Time .... ~.. ..................... ~: ................... Minutes t o -- Total Flow Time . . .~; ..................................... Minutes T -- T~mperature Rankine ................................... '~. °R Z ~ Compressibility Factor ..................................... ,/IJ ~___ Viscosity Gas or Liquid ................................... CP Log ~ Common Log · Pofentiomefric'Surface Reference to Rotary Table When Elevation Not Given, ' Fresh Water Corrected to I00° F. Each Horizontal Line Equal to 1000 P.s.i. Forma~t~'ion Testing Service~"~Report FEB ~_ 9 1974 HAl l lIIIIIff HI]I DUNCAN, OKLAHOMA Ticket / F L U I D S A M P L E O A'T A Date 9-19-73 Number 251626 Sampler Pressure P.S.I.G. at Surface .Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester Ho MANN Witness MR, SAVER cc. Mud Drilling Tot. Liquid cc. Contractor R. Bo MONTGOMERY. SM S Gravity. ° APl @ °F. EQ U I PM E N T & H'0 L E DA T A Gas/Oil Ratio cu. ft./bbl. Formation Tested. - Elevation 105' Kelly-- RESISTIVITY CHLORIDE Net Productive Interval 28 CONTENT All Depths Measured From Kelly bushinK Recovery Water __ @ __ °F. .ppm Total Depth 5755 I Ft. Recovery Mud @ °F. Main Hale/Casing Size 9 Recovery Mud Filtrate __ @ ~:-,'~i OF. .ppm Drill Collar Length - I.D. '~ Mud Pit Sample _ @ °F. Drill Pipe Length. 4772j I.D. 4.276" Mud Pit Sample Filtrate _:~:' @ __ °F. ppm packer Depth(s) 47 98 ' Ft. Mud Weight '7:7¢;/ CU, frei, 40 .cp Depth Tester Valve /4780' Ft. TYPE AMOUNT ' Depth Back Surface 1/2, 3/8 Cushion Ft. Pres. Valve Choke 1/4, 3/16"' Choke RecoVered " Feet of Gas flow Recovered Feet of Recovered Feet of Recovered Feet of < Recovered Feet of Remarks SEE PRODUCTION TEST DATA SHEET.°° · Gauge No. 3636 Gauge No. 3637 Gauge No. 3646 TEMPERATURE TIME Depth: 4784 F.t. Depth: 4788 Ft. Depth: 4814 Ft. 24 HourCIock 48 Hour Clock 12 Hour Clock Tool 9-19 A.M. , Est. °Fo Blanked Off no Blanked Off ~O Blanked Offyes Opened 1626 P.M. 4819' Tool 9-19 A.M. Actual 90 ?*F. Pressures '~, Pressures Pressures Closed 2 120 P.M. Reported Computed Field Office Field Office Field Office Initial Hydrostatic 26-04 2593 2593 2584 2621 2603 -- Minutes Minutes Initial 533 1022 531 1019 629 811 .~_'c Final 1963 1980 1973 1'9'73 1974 1977 158 155 Closed in 2165 2183 2162 ~174 2166 '2184 136 139 c o Flow uo'c Final Closed in Closed in Final Hydrostatic 2586 2571 2576 2581 2586 2587 Ticket F L U I D S A M P L E D A T A Date 9-19-73 Number 251626 Sampler Pressure PiS. I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District J~JCHORAGI~, cc. Oil cc. Water Tester H cc. Mud Drilling Tot. Liquid cc. Contractor R _ R' HC)N~'I~.I~IvI~.R¥ ~ ~q Gravity. ° APl @ °F. EQ U I PM E N T & H O L E D A Z A Gas/Oil Ratio cu. ft./bbl. Formation Tested. Elevation .Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT All Depths Measured From Recovery Water @ °F. ppm Total Depth Ft. Recovery Mud @- °F. Main Hole/Casing Size Recov:~P/ Mud Filtrate @ °F. ppm Drill Collar Len~ ih I.D Mud ~i¥ Sample ~ @ Mud Pit Sample Filtrate ~ @ °F. ppm Packet Depth(s) Ft. Mud Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of , Recovered Feet of . Recovered Feet of Recovered Feet of Recovered Feet of Remarks FOURTH GAUGE Gauge No. 3647 GOuge No. Gauge No. TEMPERA'lURE TIME Depth: 4818 F,t. Depth: Ft. Depth: Ft. ' 2/_~tour ClOck Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Off ~es Blanked- Off Blanked Off Opened P.M. Tool A.M. Actual t.F. Pressures Pressures 'Pressures Closed P.M. :: ' Reported Computed Field Office Field ~ Office Field Office Initial Hydrostatic 2628 2607 Minutes Minutes *~'~ Flow , Initial 617 1075 .~_'r- Finol 1981 1979 Closed in 2173 2180 ~ Initial c o Flow : -- 8= Final ~c~ Closed in Initial ~ Flow - ~_~. ~ Final Closed in .___ Final Hydrostatic 2610 2591 Casino perfs. 4839-4927' .87" Bottom choke. Surf. temp, 49 'F Ticket' No ..... 251626 Gas gravity. Oil gravity C-OR Spec. gravity Chlorides ppm Res. Date 9-19- 7 3 Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD p.m. Iiubble 1626 hose Tool opened 1630 1/2" Gas to the surface 1636 1/2" 1000 Mud to surface 1640 1/2" 1100 Gas ~-~-h' "'.; 1650 1/2,, 1125 ~.! Stable flow :.::'_ 1 655 3/8ii .....!125 ' Changed chokes 1700 3 /8" 1 175 Stable flow 1 732 1/4" !.7300 Changed chokes 1800 3/16' 1750 Chanmed chokes · 1822 3/16' 1860 Stable flow 1840 3/16' 1880 1 MCF Stable flow 1 904 3/16' 1 880 Closed tool & rever:;ed out. very str, blow duration of test, some signs of mud &wat er ~__ __ __. 2120 Pulle;%_~ool loose _ , . , · ,, Gauge No. First Flow Period 3636 j Depth Time Deft. I PSIG Temp. .000" I Corr. .0000 1022 (,0960-C 1489) 1167' 1571 18351 1619 ..... 2502 j 1788 (.3500-i 1861) ..... .3836. 1927 ~ 1980 .... First Closed In Pressure 10 . 11, Time Deft. .000" .0000 .0068 .0135 .0203 .0271 .0338 .0406 .0473 PSIG Temp. Corr. 1980 2084 2110 2137 2156 2168 2181 2190 .0541 2196 .4503 I 1963 .0609 2201 5170 J ,0676. .0744 .1724 ,_27...05 ,3_6_8_6 .4700~ 2207 2211 2185 2 L83__= 2183 ,I 21B3 , Gouge No. 3637 Depth 4784' Second Flow Period Time Defl. .OO0" PSIG Temp. Corr. Clock No. 7031 Second Closed In Pressure Time Defl. .000" PSIG Temp. Corr. ITicket 24 hour No. 251626 FIoW'P6'riOd Time Deft. .000" 4788' Clock No. 9299 48 hour PSIG Temp. Corr. Third Closed In Pressure Time Defl. .000" PSIG TemD. Corr. .O000i 1019 .0000 1973 .0480~C 1485' .0034 2050 .0585* 1562 ·0068 2100 .0919! 1610 .0101 2131 .1060FC 1610i! .0135 2150 · 1253' 1778 .0169 2166 .1587! 1842 .0203 2178 (.1750~C 1854' .0237 2184 '..' ..... . ..... .1922 1919 .0270 2191 .2256 1955 .0304 2197 .2590 1973 .0338 2200 .0372 2205 ji 0862 2176 2176 2174 Reoding Intervol ** II .1352 .2350 M inures REMARKS: C = choke change *First interval is equal to 35 minutes. **First 11 intervals are equal to 2 minutes each, next 3 intervals are equal to 29 minutes each, last interval is equal to 30 minutes. SPECIAL PRESSURE DATA Gauge No. 3646 I Depth 4814' Clock No. 4609 Secon~ Closed In Pressure ~2 2030-k;,, 1510), 0138 .2391.,,, !575 . 0275 . 3758 I 1623 I/ .0413 · 51241 1782' 0688 t Ticket hour No. Third Flow Period 2 i1626 Fi rst First Second Third Flow Period Closed In Pressure Flow Period Closed In Pressure Temp. Log Temp. Temp. Log Temp. Temp. Log Temp. .000" Corr. ,000" ~ Corr. ,000" Corr. .000" Corr, .000" Corr, .000" Corr. 1977 2052 2103 2138 2157 2171 .0826 2182 .0964 2189 .1102 2198 .1239 .1377 2203 _.1515 ,3511 . .9570 2206 2212 __ _ 2184 ,,, 2184 ....... 2184 ,( 2184 (.718o- 8 i . 7857 .0590 '14 , 15 1848 1861) lg23 1962 1977 ,., Gauge No. 3647 . oooo I.(.o99o- .2531 .3£o5 (.3530-; 153o) 1577 1628 1629) 1785 1848 1862) ..3880 _.4555 .5230 1927 1962 1979 Recciing Interval 20 I[ 0000 0068 0136 0204 0272 0340 0407 0475 .0543 .0611 .o679 . O_7_~Z_] .1732 Depth 1979 2033 2110 2140. 2159 2173 2182 2191 2198 2203 2206 2212 2184 __27171 I 2184 3701 1 ........ [ 2184 A79g I J 2180 4818 ' Clock No. 8739 24 hour REMARKS: Minutes": C = choke change *First interval i.~ eauml to 35 minutes. **First 11 intervals are equal to 2 minutes each, next 3 intervals are equat to 29 minutes each, last interval is equal to 30 minutes. LITTLi"I SPECIAL PRESSURE DATA ./ Reversing Sub ................ Water Cushion Valve .......... Drill Pipe Drill Collars ...................... 6.12" 5" 5" 5" 5" 5" 5" 5" Ia D. BI! 4.276" .87" 3.75" Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler ................. Hydro-Spring Tester ......... ' ....... Multiple CIP Sampler ............... ExtensiOn Joint AP Run Case Jar Hydraulic . . ;~ ........... . VR Safety Joint .......... Pressure Equalizing Crossover ......... Packer Assembly ...... RTT S ........ 8; 10" . 3.75" ..~$7" Distributor ........................ 251626 LENGTH DEPT~~ 1! 4772' 5.41' 5.02' 4.04' 4.04' '5..O7' 3.48' 4.64' 4676' 4780' 1,62t' :~ 4784 ' '~788' 4798' ' Packer Assembly ................... Flush Joint Anchor ................ Pressure Equalizing Tube ......... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Packer Assembly ................... Anchor Pipe Safety Joint .......... Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor ................. ___Z. gg" BT Case 3o88" Blanked-Off 8.'['. Running Case ....... 3.88" HT - 500 4.05' 4..10' 1.08~, , 4814' _ 4816' 6. glgt I I J'l'l Jr ~ OF4 - Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D P s -- Extrapolated Static Pressure ............................... Pslg. P F -- Final Flow Pressure ...................................... Psig. p o, --_ Potentiometric Surface (Fresh Water* ) . . .- ................... Feet Q = Average Adjusted Production Rate During Test ................ bbls/day Q, _-- Theoretical Production w/Damage Removed .................. bbls/day Q9 --Measured Gas Production Rate ............................ MCF/D R -- Corrected Recovery · bbls r ~, _ Radius of Well Bore ........................ ~ ............. Feet t · -- Flow Time ............................................. Minutes t o ~ Total Flow Time :, Minutes T -- Temperature Ranklne ................. ~ ................... °R Z = Compressibility Factor ..................................... ,~j ~ Viscosity Gas or Liquid ................................... CP Log ~ Common Log · Pofenfiomefric Surface Reference to Rotary Table When' Elevation Not Given, Fresh Water Corrected to I00° F. Each Horizontal Line Equal to 1000 p.s.i. Form~'ation Testing ServiCe Report FEB ! 9 1974 D~.ViSION OF OIL AND GAS HAl l lIIIItl I~Dtll SER I/I~, E$ DUNCAN, OKLAHOMA Ticket F L U I D S A M P L E O A T A Date 9-24-73 Number 251627 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALT, District ANCHORAGE cc. Oil i cc. Water Tester MR. MANN Witness MR. SAVER cc. Mud Drilling Tot. Liquid cc. Contractor R. B. MONTGOMERY BC S Gravity. o APl @ °F, EQ U I PM E N T & H O L E D A TA Gas/Oil Ratio. cu, ft./bbl. Formation Tested 108 ' Elevation 1 m Ft. RESISTIVITY CHLORIDE Net Productive Interval .Ft. CONTENT All Depths Measured From Ke 1 ly Bushing Recovery Water~ @ ~ °F. .ppm Total Depth 3300" Ft. Recovery Mud __ @ __ °F. Main Hole/Casing Size 9 5/8" 43.5# Recovery MU~J Filtrate ~ @ °F. ppm Drill Collar Length i~' - I.D Mud Pit SamPle ~ @ -- OF:' Drill P:ipe Length 3182" I.D. Mud Pit Sample Filtrate @ °F. ppm Packer Depth(s). 3 216 ~ ~ Ft. Mud Weight 77#/cu. ft. vis .cp Depth Tester Valve -3198' '.Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke ~" - 3/8" Choke , Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks See production test data., sheet ..... "' I Gauge No. 3647 - Gauge No. 3646 Gauge'No. 3637' TEMPERATUREJ TIME _ Depth: 3202' F.t. '.3epth: 3206' Ft. Depth: 3231' Ft. . 48 Hour Clock 24 Ho(Jr Clock 24 Hour Clock Tool A.M. ....Est. °F. Blanked Off No Blanked Off No Blanked Off Yes Opened 1613 P.M. 3237 ' @ ' Tool A.M. Actual 74 ?°F; .... Pressures Pressures Pressures Closed 1848. P.M. , Field Office Field Office Field Office Reported Computed Initial Hydrostatic 1649 1666 1643 1667 1646 1670 Minutes Minutes ..-~ Initial 53 735 q 140 66 ~ 171 848 r,.c Flow .... bT.~. Final 1421 1491 q 1416 1497 q 1406 1495 Q 63 63 Closed in 1526 1545 1521 1-542 1526 1534 92 92 ~ Initial c o ~ Flow °u'c Final Closed in Initial >_.9 Flow ~_.~, Final _ .__ Closed in Final Hydrostatic 1649 1666 1643 1667 1629 1670 Q Ques tional~le _ · Ticket F L U I D S A M P L E D A T A Dote., ,--, ,-,cl-°/'-'/q Number 251627 Sampler Pressure P.S.I.G. at Surface Kind Halliburton of Job HOOK W2~LLT, District Az~TCHORAGE Recovery: Cu. Ft. Gas cc. Oil cc. Water Tester ~. ~ Witness MR SAVER · cc. Mud Drilling Tot. Liquid cc. Contractor R. B, MONTGOMERY mC S Gravity. o APl @ °F. EQ U I PM E N T & H O L E DA TA Gas/Oil Ratio cu. ft./bbl. Formation Tested Elevation Ft. ' RESISTIVITY CHLORIDE Net Productive Interval. .Ft. CONTENT All Depths Measured From Recovery Water __ @ __ °F. ppm Total Depth .Ft. Recovery Mud ~ @ ~ °F. Main Hole/Casing Size. Recovery Mud Filtrate @ °F. ;~;;~pm Drill Collar Length. I.D. Mud Pit Sample ~ @ --__ °F. '~ Drill Pipe Length. I.D ' Mud Pit Sample Filtrate ~ @ __,°F. ppm Packer Depth(s) Ft. Mud Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of Recovered , Fee? of Recovered Feet of - Recovered Feet of -. Remarks -_ ,,_ FOURTH GAUGE: Gauge No. 3636 Gauge NO. Gauge No. TEMPERATURE 3 236 ' TIME Depth: Ft. Depth: Ft. Depth: Ft. ' '12 Hour Clock Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Off Yes glanl~ed. Off Blanked Off Opened P.M_:_O 3237' @ Tool A.M. Actual 74 ?oF. Pressures Pressures Pressures Closed P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic. 1670 1683 Minutes Minutes Initial 166 859 i._~ Flow .~'r' Final 1414 1542 Closed i,~ 1524 1544 ~ Initial ..... c o Flow ..... ~o'c Final Closed in Initial ~ o Flow ~_~-'- Final ....... Closed in Final Hydrostatic 165.2 1683 ""'-'~° '- ".'.^. Iz'(-31~I~AATI~IX! TlZqT I-IA'T'A ................. ,',, ,d Casing perfs. 3268' - 3269' 48 ' Bottom choke Surf. temp. 'F Ticket No.., 251627 Gas gravity . Oil gravity, GOR Spec. gravity Chlorides., ppm Res. @ , 'F Date ' Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD ~ubbl( 4' 13 PM Hose Opened tool 4:20 ~" 1150 Gas to surface 4-35 ~"~ 1150 Stable pressure .. , 4'47 3/8' 1250 5' 16 ·!I 3/8' 1250 Close~'tool and reversed 6:48 Pulled loose -- -. .- ,, ., -- Gauge No. 3647 First Flow Period j Depth 3202' First Closed In Pressure Second Flow Period Clock No. 9299 Second Closed In Pressure JTicket 48 hour No. Third Flow Period 251627 Third Closed In Pressure Time Deft, PSIG Time Deft. t -I- ~ PSIG Time Deft. P$1G Time Deft. t-f-8 PSIG Time Deft. PSIG Time Defl. Temp. Log Temp. Temp. Log.---~--- Temp. Temp. Log .000" Corr. .000" T Corr. .000" Corr. .000" Corr. .000" Corr. .000" 735 Q .0000 1491 Q 1016- .1530 1545 1409c) .0000 0050 0110 0134 0218 0302 1332 0386 1283 1318 1318 1311¢ 1393 0470 1313 0554 0638 0722 1414 O8O6 1421 0890 1425 0974 1427 1060 ,1491SC G~uge No. 3646 Depth 3206' Clock No. 8739 24 hour .0000 0100 ( 0200 0265 1337 .0430 1281 .0595 1315 .0760 1316 .0925 1313 · 1090 1311C · 1255 1393 · 1420 1413 .1585 1421 ~ 2 .1750 1423 ~3 .1915 1425 66 q 1026' Z407C) 2080 ]5j Recding Interval .0000 .3070 1497 Q 1542 REMARKS: *Interval = 3 minutes C : Choke Change Q = Questionable PSIG Temp. Corr. . . Minutes SPECIAL PRESSURE DATA .,.r,-,.,., Gauge No. 3637 J Depth 3231' Clock No. 7031 , I Ticket 24 hour No. 251627 Third FIo¥ Period First First . Second Second Third Flow Period Closed In Pressure Flow Period Closed In Pressure Closed In Pressure j Time De fl. PS.!G Time Defl..~ PSIG Time Defl. PSIG Time Defl..~ PSIG Ti~e Dell. PSIG Time Defl...~_ Tefnp. Log Temp. Temp. Log 'Temp. Temp. Log Temp. .000" Corr. .000" Corr. .000" Corr. .000" Corr. .000" Corr. .000' Corr. · 0000 848 . 0000 1495 .0101 (..0._Z.20 .0269 1031' 1405C) 1345 .3030 1534 · 0437 1282 · 0605 1318 ,077_3. 1321 ,09gl 1316 ,1109 1314C __~.1.277 1390 · 1_445 1409 ,1_613 1416 · 17..81 1418 · 1949 1419 1495 SC 1 ·2120 Gauge No. I ct'0000 .0206 21 (.0450 3! .0550 4 i .0894 .1238 · 1582 · 1926 · 2270 ]~ . 2614 __,~ .2958 11 i ,3302 t2j. , 36.46 ~3i ·3990 14 .4330 3636 Depth 3236' Clock No. 4609 12 hour 859 1046' 1419c)t 1353 ,0000 1542 · 6190 1544 1294 133 l 1333 1329 1327C 1404 1421 1426 1428 1430 Reading Interval 5 Minutes REMARKS: *Interval = 3 minutes SC = Surface Closure C = Choke Change Q = Questionable L, II'TL.[' I '~ II~INTEO IN U,S.A., x. SPECIAL PRESSURE DATA Reversing Sub ................. Water Cushion Valve Drill Pipe ...................... Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ............... Multiple CIP Sampler .............. ~;~ar~---!~t: .. A-. P. - Case ...... AP Running Case ................. .:. Hydraulic Jar ................ VR Safety Joint ....... Pressure Equalizing Crossover ......... RTTS Packer Assembly ................... O~ D. 6.12" 5" 5t~ 5" 5" 511 5" 8.10' lo D. mtI 4. 276" .87" 3~ 75" 3.75" .87" 1.62" Distributor ........................ Packer Assembly .................... Flush Joint Anchor .......... Pressure Equalizing Tube ........ Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Packer Assembly ................... Anchor Pipe Safety Joint ........... Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor ................. Blanked-Off B.T. Running Case .... .(.2.) HT- 500 .251627 · LENGTH 1I 3182' 5.41' 5.02' 4.04' 4.04' 5.07' 3.48' 4.64' 2.88" 2. 259" 8.65 ' 3.88" - 4.05' 3231' 3.88" - 4.10' 3236' - - 1.08' 3237' DEPTH,' 3093' "' 3198 ' 3202' 3206' 3216' Ps Q Q, Q~ R r. t to T Z Log -- Comm~°n Log oved Max ..... MCF/D OF4 ~ Theoretical OPen Flow Potential with/Damage Removed Min ..... MCF/D ~ Extrapolated Static Pressure ............................... Psig. ~ Final Flow Pressure ...................................... Psig. --'Potentiometric Surface (Fresh Water * ) ...................... Feet -- Average Adjusted Production Rate During Test ................ bbls/day -- Theoretical Production w/Damage Removed .................. bbls/day ~ Measured Gas Production Rate ............................ MCF/D --- Corrected Recovery ....................................... bbls -- RadiusOf Well Bore ...................................... Feet = Fiow Time ............................................. Minutes = Total Flow Time ....................... ~ ................. Minutes --- Temperature Rankine .................................... °R -- Compressibility Factor ..................................... = Viscosity Gas or Liquid ................................... CP .. * Potentiometric Surface Reference to Rotary Table When Elevation Not Given, Fresh Water Corrected to I00° F. Each Horizontal Line Equal to 1000 p.s.i. rmation sting Service RePo~~t FEB 1. 9 ~J74 DIVtSI9,~I 0.~. OIL ArID GAS HAl l lII IIII f lIIII SER brl P, E$ DUNCAN, OKLAHOMA 7 Ticket · F L U I D S A M P L E D A T A Date 9-20- 3 Number 251587 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WA[~ District ANCHORAGE cc. Oil cc. Water Tester m C~'~8~ Witness SAV~R cc. Mud Drilling ' ' Tot. Liquid cc. Contractor R. B. MONT~R¥ ~ $ . Gravity ° APl @ °F. EQ U I PM E N T & H O L E DA T A Gas/Oil Ratio. cu. ft./bbl. Formation Tested Beluga Elevation 105' K,B, Ft. RESISTIVITY CHLORIDE Net Productive Interval 19 ' Ft. CONTENT All Depths Measured From Kelly Bushing Recovery Water __ @ -- °F. ppm Total Depth 4830' Ft. Recovery Mud ~ @ ~ °F. Main Hole/Casing Size 9 5/8" - 43.5# Recovery Mud Filtrate ~ @ °F. ..ppm Drill Collar Length - i.D - Mud Pit Sample @ °F. Drill Pipe Length, 4524' I.D 4 276" Mud Pit Sample Filtrate __ @ __ °F. ppm Packer Depth(s) 4550 ' Ft. Mud Weight 77# Cu. Ftys 40 cp Depth Tester Valve 4531' Ft. TYPE AMOUNT Depth Back Surface. ,, Bottom Cushion NONE Ft. Pres. Valve 4526' Choke -~ - 3/8,,- Choke 5/8" .~" Recovered Feet of . ~ Recovered Feet of ~ B Recovered Feet of ~ Recovered Feet of Z Recovered Feet of Remarks Tool opened with a very weak blow - slowly increasing to a strong blow in 14 minutes, SEE PRODUCTION TEST DATA SHEET FOR REMAI~.~R OF THE REMARKS, o o Q = QUESTIONABLE, Gauge No. 3636 Gauge No. 3637 Gauge No. 3646 TEMPERATURE TIME Depth: 4536' Ft. Depth: 4540' Ft. Depth: 4566'Ft. ,, 24 Hour Clock 48 Hour Clock 12 Hour Clock Tool A.M. ,, , Est. °F. Blanked Off NO Blanked Off NO Blanked Off YES Opened 12: 36 P.M. Tool A.M. Actual 74 "F. Pressures Pressures Pressures Closed 4:53 P.M. ,,, Field '? Office Field Office Field Office ' RePorted Computed Initial Hydrostatic 2440 2454 2507 2472Q 2463 2456 Minutes Minutes ~.~o Initial 37 46 34 43 52 108 ~-r. Flow . ~:~. Final 1248 1267 1251 1258 1259 1267 166 166 Closed in 1945 1963 1938 1955 1939 1960 91 91 ~ Initial i'~Fl°w Final Closed in Initial .~_.o_ Flow ~... Final Closed in .... Final Hydrostatic 2421 2434 2455 2445 2428 2441 ____ _ · · · Ticket F L U I D S A M P L E D A T A Date 9-20-73 Number 251857 Sampler Pressure,, P.S.I.G. at Surface Kind Halliburton Recovery:· Cu. Ft. Gas of Job HOOK W.ATJTJ District ~CI'IO~GI~- cc. Oil cc. Water Tester m C1~6._1~ :Witness SA~r~. cc. Mud Drilling Tot. Liquid cc. Contractor Gravity. ° APl @ °F. EQ U I PM E N T & H 0 L E DA TA Gas/Oil Ratio. cu ft./bbl. Formation Tested .. Elevation_ Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT All Depths Measured From Recovery Water ~ @ °F. ppm Total Depth Ft. Recovery Mud .. @ ~ °F. Main Hole/Casing Size Recovery Mud Filtrate ~. @ °F. ppm Drill Collar Length I.D.~ Mud Pit Sample ~ @ ~ °F. ~ Drill Pipe Length ' .I.D. Mud Pit Sample Filtrate ~ @ ~ °F. ppm Packer Depth(s) Ft. Mud Weight vis ..cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of ~ Recovered Feet of · Recovered Feet of Recovered Feet of o_ Recovered Feet of Remarks FOURTH GAUGE Gauge No. 3647 J Gauge No. Gauge No. TEMPERATURE 4570' TIME Depth: Ft.I Depth: Ft. Depth: Ft. ZZ~ Hour Clock Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Off Y~J~ Blani~ed Off Bianked Off Opened P.M. Tool A.M. Actual °F. Pressures , Pressures , Pressures Closed P.M. Fie=d Office Field Office Field Office Reported Computed ~lnitial..~.r_ FIowHydr°statiClnitialI 352453 972462 Minutes Minutes uT-~.. FinalI 1247 1269 Closed in 1963 1962 ~ Initial c o Flow O-~. ~ e Final Closed in Initial ._~.o_ Flow ~_~. Final Closed in Final Hydrostatic 2453 2/+41 L, Casing perfs. Bottom chok~ 5/8~1 Surf. temp *F Ticket No- 251587 Gas gravity Oil gravity. ~GOR Spec. gravitY. .Chlorides ppm , Res. .~ 'F .,, Date . 9-20-7~ Choke Surface Gas Liquid " Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD 12:36 ¥' Opened tool . 1:42 ¥' 440# Changed to 3/8" choke 2:26 3/8" 660# Changed to ¥' choke 3:22 ~" Closed in 4:53 ~il Pulled loose and Reversed out.., -- ,., , ,, , Ticket Gauge. No. 3636 Depth 4536' Clock No. 7031 24 hour No. 251587 . First First Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Deft. I PSIG Time Deft. t -~- ~ PSIG Time Defl. PSIG Time Deft. 1 t -1L ~ PSIG Time Deft. PSIG Time Deft. t qt. ~ PSIG Temp. Log Temp. Temp.~ Log Temp. Temp. Log Temp. .000"I Corr. .000" ~ Corr. .000" Corr. .000" e Corr. .000" Corr. .000" ~q Corr. ! .0535 432* .0233 181'3*~v 2 .1037 593 .0433 1855 3 .1539 639 .0633 1877 4 .2041 636 .0833 1894 5 (.2210 636C) .1033 1907 6 .2543 769 -- .1233 1918 7 .3045 822 .1433 1-925 . 81 ..3547 833 .1633 1932 _ 9 (.3720 833C) _ .1833 1940 ...... lO .4049 1046 .2033 1945~' _ ...... . 11 .4551 1193 .2233 1951 12 .5053 1246 .2433 1954 ... 13 .5550 1267 .2633 1958 14 .2833 1962 Gouge No. 3637 . Depth 4540' Clock No. 9299 hour 48 ' , 0 .000 43 .000 1258 1 .0270 416' .0117 1808'* 2 .0523 582 .0217 1847 3 .0776 630 .0317 1869 4 .1029 625 .0417 1885 5 (.1120 625C) .. .0517 1899 6 .1282 7'57 .0617 1907 7 ,1535 .813 _ ~.0717 1916 L'!. 8 .1788 824 .0817 1924 . 9'(.1880 825C) .0917 ......1930 lo .2041 1041 .1017 1936 11 .2294 , 1182 .1117 1942 12 .2547 11237 .1217 1945 .. 13 .2800 11258 .1317 1950 "' ,. I _1471.7 1954 I 15~, .!59_0 1955 .... 'Read!ng Interval 15 6 Minutes REMARKS: '* INTERVAL ' 16 MINUTES. "** INTERVAL = 7 MINUTES. C = CHOKE CHANGE. ' "-""""""'""'""' SPECIAL PRESSURE DATA -,.r.,.,.,., ~uge No. First Flow Period Time Defl. I PSIG Temp. .000" Corr. · ooo t lo8 640 .5214 76'6' .6243 825 .7272 836 (.7630 836C) .8301 1038 .9330 1192 1.0359 1247 1.1390 1267 3646 I Depth First Closed In Pressure Time Deft. .000' .000 .1696 .2103 .2510 .2917 .3324 .3731 .4138 .4545 .4952 .5359 · 5766 .6180 PSIG Temp. Corr. 1267 1807'* 1848 1873 1889 1901 1911 1920 1927 1932 1939 1944 1948 1953 1956 1960 4566' Second Flow Period Time Deft. .000" PSIG Temp. Corr. Clock No. 4609 Second Closed In Pressure Time Deft. Log-~ .000" PSIG Temp. Corr. ITicket 12 hour No. Third Flow Period Time Deft. .000" PSIG Temp. Corr. 251587 Third Closed In Pressure Time Defl. Log.L.~' .000" P.~IG Temp. Corr. ;auge No. 3647 Depth ~570 000 197 .000 1269 i 05361442' ·0233 -1809'* -~--0-~ §/~ .0433 1851 11540jl 649 .0633 1876 2042 642 .0833 1892 .1033 1904 773 829 837 1042 1914 Clock No. 8739 hour 24 Reading Interval 15 6 Minutes REMARKS: * INTERVAL = 16 MINUTES. ** INTERVAL = 7 MINUTES. C = CHOKE CHANGE. PRINTED IN U,$.A. SPECIAL PRESSURE DATA -. - 25.,, ~87 ~ Reversing Sub ................. Water Cushion Valve ......... Drill Pipe ....................... Drill Collars ...................... Handling Sub & Choke Assembly ..... Dual CIP Valve ................... Dual CIP Sampler ................. Hydro-Spring Tester ............... Multiple CIP Sampler ............... AP CASE .r~d~~. ................... AP Running Case Hydraulic Jar ............... VR Safety Joint ............... Pressure Equalizing Crossover ......... Packer Assembly ...... .~.~. TS ........ O. D. 6.12" 5I! 5.00" 5.00" 5.00" 5.00" 5.00" 5.00" 8.10" lo Do LENGTH DEPTH 3~00" 4.276" .87" 1.00" 3.75" 3.75" .87" 1.00" 1.62" ' 1! 4524' 5.41' 5.02' 4.04' 4.04' 5.07' 3,48' 4, 64' 4428' 4531' 4536' 4540 ' 4550' Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................ Pressure Equalizing Tube ........ Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... F I uj~h. ,~o.i n tcA~o r ................. Blanked-Off B.T. Ru~_n~(~sse ....... 2.88" 3.88" 3.88" 2.259" 8.65' 4.05' 4.10' 1.08' 4566' 4570' 4571' Each Horizontal Line Equal to 1000 IO.s.i. _ ! ATTACtiMENT ?~9 ~ COMPANY CORE BARREL ~ -.' MUD TYPE F' '- -CORE .OIL, 'APl .- : ;- Standard Oil Co. of Calif. ._ · Porosity Depth., Feet Percent Sch I umberger S i dewa i I .. _ ..__~nter Base . ./. 'F -' .: :-'...' '. ' ' · .... .. CORE ANALYSIS DATA . Air'. ' .' Permeab i'! i ty - mci, 3220 '3220 5284 3284 : 3333 3340 3340 "]!3370 ...-!3396 ,, 3433 3490 3509 3553 3554 3555 3579 3629 - 3653 3653 3702 3746 3777 3795 3855 3894 3894 3954 · · 4OO0 4073 o cov r ·---'-'. ': ' No Recovery No Recovery . ' 35,3 .'-" 1.0 34.9 No Recovery 33.8 2'.9. . : '35.0.-: '' ';5.:2 -" ' '"'-.-..:- 38.2]".;']':-:': ' ~ 1260'.'_ :. '. 36.9 32 · 31.6 _']:- -"-- il6 ':':' - 34.2 ,- !46 No Recovery . No Recovery 34.2 3.0 33.0 . !14 . -~ 29.9 -- 165 30.1 .... 23 No.Recovery' 23,6 20 31.8 . 63 27.8 15 31.2 -54 26 4 52 No Recovery 24.9 4.-I .. No Recovery . 28.7 17 27,6 127 WELL FIELD COUNTy STATE Dens i ty · Sand Gra i n - _ BRU 212-24 BELUGA RIVER UNIT Sec. 24T-13N-lOW KENAI ALASKA . ,, ., Description 2.69 2.73 SLTST,..VFG :NOSFC '2.68 2.71 SS, VF-'FG, NOSFC 2.65 SS, F-~MG, NOSFC 2.71 SS ,VF-FG, NOSFC 2.74 SS', MG, NOSFC 2.67 2.76 2.68 SS. FG. MPSFC 2.68 SS ,MG, NOSFC.. 2.71 2.69 .............. ~SS~--MG, NOSFC 2'72 SS', FG , NOSFC 2.71 SS ,FG, NOSFC 2.72 SS,FG, NOSFC 2.71 SS ,M-FG, NOSFC' 2.72 2.72 SS,VFG, NOSFC 2.68 SS , F-MG , NOSFC · PE~RO!.EUM ?ES~G SERVIC~: ' ~ ~ /-~,' ~ELL; . · Standard Oil Co. ~. Cai if. FIELD: ,! Sch I umb~rger S i dewa I I S,~-,p ! es COUNTY: --' ~ STATE : ~ . ' . ' m-- --CORE ANALYS I S DAT ' "~- - ,,-;:;ntlnued) - .-. . · ..:t"' . Air · ' ....... Poros i ty Permea b i t i ? v Depth,- Feet 4207 27.3 16 4248 21.2 74 I ' 4285 ' Dens i ty .3and Grain qm/cc 2,67 2.48 2.71 2.'6A 44a5 27.8 51 .2.7i 4489 . : ': 2.7.4 "'- i 16 2.69 4527 . ", 2'5.9 15 . "2.70 4620 4695 4695 - 4773 4811 4852 AO'70 4879 4938 5026 5095 5O95 5176 5176 5195 5226 5337 5363 5394 5419 -. "5476 5575 5655 23.9 28.6 NO Recovery,. . - . 27.6 21.9- -' '' 23.8 o~ Recovery 25,0 23.0 - : 23.9 No Recovery 26. I '5.9 198 . . . 95 3.0 1.6 . ..:.0.7 36 146 2.73 2;45 2,66 2.67 2.64 2.71 2,69 2,70 2,54 - No Recovery 24.2 25.6' 23,3 . 28.3 25.4 25.3 · 23.5 20.7 28.2 26, !'- .. 32 46 16 473* 14 '33' ! ! ' ' 163 .869 ,. 9.3 2.65 2,62 2.69 2.70 2.72 2.72 · 2.72 2.70 · 2.63· 2.73 o. *Fraczu-ed V~.. IVUt~i I I 71.,,1 BRU 212-24 BALUGA RIVER UNIT KENAI ALASKA .. DescriPtion SS,VFG, NOSFC SS,~4-FG, NOSFC SS,FG~' NOSFC St, TST, NOSFC SS,FG, NOSFC $$,F-MG, NOSFC SS,FG,. NOSFC SS~FG, NOSFC SS,FG, NOS.FC · · ss,F-MG, NOSFC SS,VFG, NOSFC SLTST, NOSFC SLTST, NOSFC SS,VFG, NOSFC SS,F-MG, NOSFC SS,FG, NOSFC SS,FG, NOSFC SS,FG, NOSFC SLTST SS,VFG, NOSFC SS,VFG, NOSFC SS,VFG, NOSFC SS,FG, NOSFC SS,F-CG, NOSFC SS~VFG, NOSFC . PET~~UM~TESTING:. SERVI~E~.: ' ~:;" . S*andard Oil Co. ol bliP. * Sch I umberger S i dewa I I Sanp I es , o .~.L; 8RU 212-24 F,~LD: BALUGA RIVER UNIT COUNTY; KENAI STATE: ALASKA , ' -- .. - ' - · ' ' :- ' - ' CORE ANALYSIS' DATA '~-(.Contlnued) ,-"-'.. :. ,. ...F. ' >. ·' .' ~ _.'.] ' .':-: .'.- ' ' .... ''"' ~ - '- ~' ~': '~ ' ~:": ' "' '~'"'~'"~ ' ....-" Air ' ' - Density " : .:~' ' -- -;.. ~ ....· · ."~ ......... ' -' ..... Poros. ity - Permeability Sand 'Grain , ..- '-'D~P. th, [e? -Percent md.' ,- _ .___gm/cc · - 5775 - 24.6 ] 567~] 2.64' .SS, ~' 5807 ' InS~fficien~ Recovery .... .... .. 5810 24.4 i09- · ' 2.~4 ss, Fa, RoSFc , , 5825 22.8 5..7 2.73 ss, FG, NOSFC ' 5856 23.~ .. 3.0. 2.72 SS, FG, NOSFC ' L-.--'--;. :~ 5886 ' 23.6 -.' ~-->-.4.6 2.74 ss, FG, NOSFC . . . 5896 No Recovery _. 5896 22.1 ~ Description F-MG, NOSFC 2,73 SS , F-MCa, NOSFC 5913 ::' "' 24.0 .... ' -12 2.94 2.66 SLTST, NOSFC · SS, FG, NOSFC ' 2.75 SLTST, NOSFC 6012 i· 25~.3 ' 13 ~.~ '..' 2.75 SS,F-VFG, NOSFC ' 6020 23,9 '. '-'23 ' -'.' 2.67 SS, F-VFG, NOEIFC · 6063 -----~-22.0 "'.- ..-':"'"--'-1:2',4.-: -' ' 2.73 Ss,Fa, NOSFC . - ] -:. · ,.. · · _ . - . . : >.---.-... ' ..] 6129 '6142 6143. 6173 22.6 23.7 No Recovery 25.5' - . 22.7 62'28 · · 6229 6289 6293 No Recovery 22,5 '...- 23.3 ' '..' 3.1 . 2.69 : . . - "' 2650* 2.7 I ... - 1,7...: .':'.].' 2.74 134 - ' -'- 2,69 3,.4 ~ . ..: 2,72 30 '. 2,72 --*Fractured SLTST~ VFG, NOSFC SLTST, NOSFC SLTST, NOSFC SLTST, NOSFC · SS,FG · ~ COMPANY -.;'.'CORE BARREL MUD-TYPE ~ CORE OIL, "APl . . . gepth, Feet 3291 ' II" 3292 ' 9" 3293 ' 9" -'3294' 8" -3295 ' 6" 3296 ' 6" 3297 ' 6" PET£pLEUM TESTING '~$ERVICE ~) ......... - --" , October 1973 '~ -:'~ ---~ i ' ~ ..... ~' ' STANDARD OI'L. ¢O. OF gAL i F, WELL BRU 212-24 3- I/2" Convent iona I · _ Water' Base ' CORE ANALYSIS DATA FIELD BELUGA RIVER UNIT Sec. 24T.-13N-IOW COUNTY KENAI STATE ALASKA Poros i ty Permeab i I i ty Sand Gra i n Percent md. .._. ~gm~c_c 34.5 17 6.4 12 0.7 0.03 .0.5 0,4 2.70 2.68 2,69 2.71 3.31 2.69 2.59 36.~ 35'.7 7.5 35.0 35.0 3304'8" 3305.'-7" 3306'4" 3307'8" 3308'6" 3309'8" 3310'7" 33|l'4" 3312'8" 3313'6" '33.14 ' 5" 3315 ' 6" 33.16 ' 7" 33 ! 7 ' I0" 3318'10" 3319'3" 3320'6" 3321'5" 3322'5" '-3323'9" 3324 ' I I" 3325 ' 7" 3326 '7" 3327 ' 8" 3328 ' 6" 3329 ' 2" 3330 ' 4" 3331 ' 4" 3332" I I" ~ 3333 ' 3" 27.6 28.8 30.6 32.0 34 . 33'.8 33.5 33.0 33.5 34.9 35,1 34.7 30.4 33.8 32.7 33.9 36. I 35.5 33.7 34.7 34.5 33.3 54.7 35.1 35;3 33.7 34.5 33.7 34.3 5.4 2.2 1.8 22 9.0 0.6 0.3 3.4 1.9 0.8 4..8 3,2 2.1 2.0 :6,5 2.1 152 96 2;6 8.8 2.1 1.5. 3.2 25 8.0 39 0,9 6.9 2.69. 2.72 2,73 2.71 2,70 2.71 2.66 2.69 2.71 2.71 ~.71 2.68 2.66 2.68 2.70 2.70 2.68 2.68 2.71 2.68 2.71 2.71 .2.72 2.70 2.65 2.72 2.69 2.73 2.68 : PE11~OLEu~ TESTING SERVICE Standard Oil Co. of Calif. ~De~p~th, Feet Per~e~_nt _ L: 3334'3" 3335' 0" 3336 ' 2" 3337' 7"' 3340 ' I 0" 334 ! ' 4" 3342 ' 4" 3343' I I" 3344 ' 5" 3345 ' 9" 3346' 8" 3347 ' 4" '3349 ' 2" 3350 ' 6" 3351 ' 7" 3352 ' 8" 3353'5": 3354 '4" 3355 ' 6" 3356 ' 9" 3357 ' 5" 3358 ' ! O" 3359' t" 3360 ' 7" 336 i ' 6" 3362 ' 7" ' 3363 ' 6" 3364 ' 8" ' - -'3365'-6" 3366 ' 6" '~,i l e #5724 October, 1973 WELL: FIELD: COUNTY: STATE: coRE':'-:A~'~Lysls DATA- (Contin'ued) Air Porosi'ty...Permeability md. 6.6 12 6;5' 0.6 0.9 0.2 5.7 2.9 1.3 1.8 Dens i ty Sand Gra i n _,, 97/cc 2.64 2.67 2.69 2.51 2.65 . 2,69 2.69 2.69 2.70 2.71 37. I 3.5t 4 32.2 33.0 27.9 27.0 29.2 32.9. 33.9 35 .'4 0.4 0.9 3.8' 0.4 0.5 1.4 0.4 0.6 '1.3 8.'9 174'' 250 1370 311 327 1860 483 1120 1050 2.74 2.67 2,44 2.73 2.73 2.71 2.70 2.72 2.69 2.72 .2.70 2.64 2.63 2.66 2.66 2.38 2.65 2.65 2.67 2.66 36;I 35;2 37.8 36.0 33.3 34.4 34.9 35.9 32.9 35.6 38.9 39. I 45,4 38.0 41.5 46.9 41.7 43.2 44.4 Page 2 BRU 212-24 BELUGA RIVER UNIT KENAI ALASKA 3367'6" 3368'6" 3369'6"' 3370'8" 33711'5" 3372'0" 3373'4" 3374'9" 3375'9" 3376'8" . 42.6 42.0 '42.9 37.4 36.2 38,9 35.5 · 35.8 36.8 34.6 950 93- 2510 475 594 838 585 659 560 424 '*Fractured 2.65 2.66 '2.69 2.65 2.68 2.67 2.69 2.67 2.67 2.66 PETROI. EUM TESI:iNG Si~RVICE Standard Oil Co. of Calif. · · · . WbLLi BRU 212~24 FIELD: BELUGA RIVER UNIT COUNTY: KENAI STATE: ALASKA '.''~ CORE'A.NALYSI.S: DATA - (Continued) Air · ' Porosity 'Permeability D~p th, Feet Percent md. 3377 ' 6,, ' 3378 ' 9" 33'79 ' 6" 3380 ' 5" 338 ! ' I 0~' 3382 ' 2" 33:83 ' 3" 3384 ' 5" 3385 ' 6" 3386 ' 4" 42~8 .40.0 - 34,0 40,6 37.4 35.6 40.6 39.2 35.2 472 "' 578 ~ 189 658 176 3O8 699 757 1360 477 32587 '4" 338.8 ' 3"" 3389 '5" 3390 ' 4" 339 ! '7" 3392 ~ 2" 3393 ' i 0" 3394 '4" 3395 ' 5" 3396 ' 8" 3397'3" '3398'5" 3399'9" 3400 ' 7" 3401 '5" 3402 ' 4" .--3403 ' I 0" 3404 ' ! 0" 5405 ' 4" 5406 ' 4" 340.7 ' 6" 3408'2" 3590'5" 3591'4" 3592'2" 3593'!1" 3598'11" 3599"5" 34.8 34.4 35.5 35.3 .35.3 36.3 -'40 .D 34.8 34.7 36.6 36,1 35.8 35.2 36. I 36.2 36.2 36.6 37.3 37.2 39.5 35.6 33.9 33,0 35.0 35.2 36.6 23.7 24.~ 417 435 642 373 163 131 133 273 48O 995: 522 551 749 . 572 209 626: 627 219 158 359 1030 36 1.3 1.3 0.1 I._.6 1.0 2.0 Density Sand Grai n gm/cc 2.68 2.69 2.70 2.66 2.66 2.66 2.67 2.68 2.69 2.67 2.67 2.66 2.67 2.67 2.69 2.67 2.68 2.71 2.71 2.67 2'.69 2.67 2.66 2.66. 2.67 2.67 2.66 2.69 2.66 2.69 2.69 2..6 2.69 2.70 2.71 ' 2.31 2.67 2.68 'PETRO'L~M TESTING 'SERVICE Standard Oil Co. of Ca W:LL:' FIELD: COUNTY: STATE: , · ~' CORE.A~ALYSlS DATA ~ (Continued) BRU 212-24 BELUGA RIVER UNIT KENA! ALASKA Depth, Feet 3600'4" 3601'9"' 3602'9" 3603'5" 3604'7" 3605,8'~ 3606'9" 3607'3" 3608'8" 3609.'4" . . 3610"4" 3611'1" 3612'11'? 3613'10" 3614'2" 3615'9" 3616'10" 3617'6" 3618'!0" 3619'3" 3620'7" 3621'6"- 3622'8" 3623'3" 3624'4" 3625'6" 3626'4!' 3627'6" 3628'9" 3629"9" 3630'6" 3631'5" 3632'4" 3633'3" 3634 ' 10" 3635!1 O" 3636'10" 3637'!0" 3638~6"- 3640'1'i" Poros i ty Percent ' 27,8 28.8 29?2 -.' 29.5 '28.2 29.3 31.3 28.5 23.4' 28.5 29.4 33.4 34.6 30.4 29.4 31.9 32.3 32. I 35.4 33.3 32.7 35.1 31.3 33.7 34.9 34.4 35,0 40.1 41.2 42.0 41 .I 37.7 ,42.0 37.0 35. '4 34,1 33.8 34 .'i 39.6 30.6 Air Permeab i I ity md. 15. -- 14- ' -I,I 0.9 0.8 2.1 0.1 2.1 1.8 0.4 1.8 0.3 0.7 0.6 0.7 0.1 25 4.8 0.7 0.4 '3.0 '110 2.1 4.7 25 17 71 366 335 245 942 549 406 142 !.5 0.9 0.1 0.1 0.1 4.8 Dens i ty Sand Gra gm/cc 2.69 2.70 2.67 2.68' 2.69 2.71 2.75 2.69. 2.71 2.68 2.70 2.70 2.59 2.70 2.70 2.65 2.70 2.69 2.73 2.75 2.74 Z. 71 2.73 2.76 2.73 2.71 2.72 2.68 2.68 2.67 2.66 2,68 2.67 2'.66 2.74 2,73 2.78 - 2.76 2,68 2,71 in PETI~OLEU~ TE~fiNG~'- ~RVI~ ,CE '/'~. Standard O i I Co. of Call r. _~...:ober, 1973 WELL: BRU 212-24 FIELD: BELUGA RIVER UNIT COUNTY: KENAI STATE: ALASKA Dep,.t..h,_ Feet ''Air Density Porosity Permeability Sand Grain Percent= md. .._ g~/~c 3641'9" 3642'8" 3643'4" 3644'4" 3650'6" 3651'6" 3652'5" 3653'6" 3654'5" 3655'7" .34,2 31.3 34~7- 35.9 42;0 41.4 35.6 35.6 36.8 40.3 ' I.I 2.67 1.9 2.67 41 '-.'- 2.67 50 2.68 972 2.69 1450 2.66 489 2.60 518 2.65 237 2.64 1630 -2,65 3656' 8" 3657' 6" 3658' 3" 3659'4" 3660 ' 2" 3661 ' 7" 3662 ' 7': 3663'4" 3664 '8" 3665 ' 8" 3666 ' 5" 3667 ' 5" 3668' 5" 3669 '4" 3670 ' 6" 367 i ' 3" 3672' 5" 3673 ' 3" 3674 ' 3" 3675 ' i 0" 34.8 4.1 3.3 3.4 12.0 34.0 35, i 33.7 41.7 40.4 39.7 41.5 · 40.2 34.3 34.8 35.2 35.6 35.9 36~3 40.3 373 <0.1 ~0.1 ~0;I 1.2 202 427 564 1340 . 963 28O 722 5O5 354 ~1.7 1.2" 0.4 0.4 0.4 0.1 2.65 2.75 2,69 2.68 2.68 2,67 2.70 2.66 2,66 2.67 2,68 2.69 2~73 2,67 2,72 2.73 2,72 2,74 2,74 2.45 3676'9" 3677'5" 3678'1" 3679'2" 3680'4" 3682'2" 3683'10" 3684'3" 3685'5" 3686'4" 35.0 37,0 .32.3 29.1 39.8 27.6~ 30.6 30.1 28.6 29.6 <o.i 0.2 lO* 2.4 0.7 2.1 0.8 3.7 2.44 2.35 I .92 2.43 2.72 2.72 2.71 2.74 2.74 ~Fractured Standard Oil Co. of Calif. Depth~ Feet 3687'6" 3688'7" 3689'3" 3690'5" 3691'8" 3692'16" 3693'6" 3694'4" 3695'8" 3696'7" ~lle O~ ~r~ 1973 wage WELL: FIELD: COUNTY: STATE: '- CORE A'N']~'LYSIS DATA - (Continued) - ~,._~ , . ~ ; ~ . . ~~,,~__ Air Density Porosity. Permeabi I ity Sand Gra Percent md. . ___gm/cc 38.4 39.6 31~4 39.8 41.6 35. I 38.2 39.3 34. I 33.9 237 223 22 366 951 178 419 1450 415 881 2.67 2.67 2.71 2.69 2.70 2.69 2.68 2.68 2.70 2.66 in BRU 212-24 BELUGA RIVER UNIT KENAI ALASKA 3697'5" 3698'9" 3699'7" 34.2 32.3 32.8 647 398 38'5 2.67 2.66 2,68 3700' 7" 3701 ' 5" 3702 t2" 3703 ' 9" 3704 ' 8" 3705' I O" 33.8 37'.3 ,~rl. 5 38. I 37.9 38.8 2070 487 2350 625 534 955 2.68 2,67 2.65 2,67 2,67 2.66 .Fo n'n No. REV. 9-30-67 0IL C GA8 WELL WELL 2. NANiE OF OPERATOR Standard Oil Company of California, WOI 3. AD~)RESS OF OPEtC~TOR STATE OF; ALASKA ~uB~rr m DEPT.~CA~S O~L AND GAS CON~RVATIO.N COMMITTEE MONTHLy. REPORT OF DRILLING.. AND WORKOVER OPERATIONS OTHER OI 99510 P. O. Box 7-839, Anchorage, Alaska 4. LeCA~ON O.F W~E~ 2000.46' South and 50.44' East of the NW.corner of Section 24; T-13-N, R-10-W, SB & M Beluga River 11. SEC., T., R., M.. I BO~i'OM HOLE OBJECTIVE) Section 24; T-13-N, R-10-W, SB &M 12. PERMIT NO. 72-25 13, REPORT TOTAL DEPTH AT E/~D OF MONiSt, C!~%-NGES IN HOLE SI~E, CASING A/VD CL~IENTING JOBS INCLUDING DEPTH SET' A/ND VOL~ USED, PEI{FO4{ATIONS, T~STS A/NTD RESULTS, FISHING JOB~, JLrHK LN HOLE ~D SIDE-T~LAC~LED HOLE .~ND A~qY OTHER SIGNIFICANT CI-IA~-~F_~ IN HOL~I CObFDITIONS. September 1973 Drilled 12 1/4" hole'from 3,204' to 6,000'. Cored intervals 3289'-3409' and 3590'-3710'. Ran Dual Induction Laterolog, Density Neutron and Sonic Logs, Proximity-Microlog and Dipmeter. Drilled 12 1/4" hole from 6,000' to 6,380'. Ran Dual Induction Laterolog, Neutron-Density, Sonic and Proximity Microlog. Cemented 9 5/8'' casing through shoe at 6,376' with 690 sacks class "G" cement and at stage collar at 4140~ with 690 sacks class "G" cement. Ran Neutron and Cement Bond Logs. Ran Formation Test 91 on intervals 6297'-6283' and 6022'-5999'. Had light blow to surface. Set permanent bridge plug at 5990'. Ran Formation Test #2 on intervals 5798,-5818' and 5766'-5780'. Had str~ng gas blow to surface. Ran FOrmation Test 93 on intervals 4839'-4843'; 4849'-4853' 4866'-4870'; 4878'-4883' ! , 4887'-4889', 4907'-4911' and 4922'-4927'. Had strong gas blow to surface. Ran Formation Test 94. on intervals 4604'-4608' and 4618'-4633'. Had strong gas blow to surface. Squeezed approximately 163 cubic ft. of class "G" cement through four 1/2" holes at 3268'. Ran.cement Bond Log from 3300'-3180'. Laid 25 sack class "G" cement plug at 5985'-5945'. ~ Perforated selected intervals with four 1/2" jet holes per foot from 5919'~to 3278'. CON FIDENT. III: ce ify e for g is e and correct 14. I herebySIGNED ~~_e_~ ANCHORAO~ , , , ' =?z.~ 'Area Supervisor DAu.~ 10- -73 d,/.i/ W. W~::I..LJ~- ' - ,, ,,, ~ , Nl~E--Report on this f~m is required for each calendar month, regardless of the status of operation~, anO must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. Form ~o. P--4 R~V. 3- I-?0 STATE (.,. ALASKA OIL AND GAS CONSERVATION COMMI~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. W~LL of Californiar W0I SUBMlrr IN DUPLICA~'E Il. NA/~E OF OP~I~ATOR Standard 0il Company 3. ADDRESS OF OP~P. ATOR '~' ~PI NUiVIER/CAL bODE 50-283-20037 LEASE DESIGNA~ON AND SE1RIAL NO. ADL-21128 IF INDIA~ A~i 1~ OR TRIBE NAME 8. L,~IT FArtl~ OR LEASE NAME Beluga River Unit 9 W~i,T, BRU 212-44 10 FLFJ~D AND POOL, OR WILDCAT Beluga River Field il SEC. T,. R. M (~OM HOLE O~rF~ Sec 24: T-13N; R-10W; P. O. Box 7-839 Anchorage~ Alaska 99510 4 ~CA~ON OF WF_J~L 2000.46' South and 50.44' East of the NW Corner Section 24; T-13N; R-10W; SB&M 12. PEiRIVIIT NO 72-15 L SB&M 13. REPORT TOTAL DEPT~I AT END OF MON~H. CI~NGES IN HOLE SIZE, CASING AND Ci!;NiEN~NG JOBS INCLUDING DEPTH SET ~ VOLU1VIES USED: PEI~FO.P~ATIONS. T~STS A/~rD HESULTS FISHING JO~ JL~NK I/q HOLE AND SIDE-T]~ACKED HOLE AND A.I~Y OTHER SIGNIFICANT CI-L&NGES IN HOLE CONDITIONS Au~us t~ 1973 Commenced operations 4:00 AM, August 19, 1973. Drove 30" conductor to 79' Drilled ahead in 17 1/2" hole to 430'. Opened 17 1/2" hole to 26" from 79' to 430~. Ran 365' of 20" 94#/ft H-40,.Buttress casing and cemented in place with 535 sacks Class G cement, premixed.with 2.4% Gel., by weight of water. Good returns throughout Job with cement to surface. Used a slurry weight of 100 pcf. ~Cut 30" conductor and 20" casing, and installed 20" 2,000 psi Class II B BOPE one20!' casing. Tested 20" casing head and casing to 400 psi. Tested choke andkill lines to~3,00.0 psi. Located cement in 20" casing at 355'. Drilled out.shoe, and~d=illad ahead in 17 1/2" hole to 980!. Pipe stuck at 927'. Circulated until_pipe free. Lost 200+ bbls. of mud. Drilled ahead in 17 1/2" hole to 3204' with.minor amounts of l~st circulation. Ran dual-induction- laterolog, sonic log, and neutron-density log from 3204' to 365'. Circulated and conditioned mud. Ran 13 3/8" 68#/ft., K-55, Buttress casing to 3202' and cemented in place with 1430 sacks Class G cement, premixed with a 2.4% Gel, by weight of water, followed by 830 sacks Class G neat cement. Good returns throughout job. Cement did not return to surface. Cemented 13 3/8" x 20" annulus with 105 sacks Class G cement through 1" pipe at 125'. WOC on August 30, 1973. NOTE --Report on this form ~ required for' each calendar month~ regardless of the status of operations, and d In duplicate with the oil and gas conservation committee byt#e ISth of the suoceeding month, u~le~ otherwism directed. ~V. 9-~9 & "Su~quent Repo~s" m Dupli~te STATE OF A~KA ~. OIL AND GAS CONSERVATION ~O~I~EE, 50-283-0037 SUNNY NOTICES AND REPORTS ~ W~ ~i]"'ENG (DO ~Ot use this ~Om ~o~ p~Opos~Js ~ dr~l] o[ to ~eege~ use "A~b~CAZ~ON .... '~O~ ~tT~" ~o~ ~uc~ 'p~O~°S~) ~- Standard Oil Compa~ of Cal&~o=:ia,, ~.O.I. , ~eluga A&~e~ - ~>AFT ~. O. ~o~ 7-839, ~cbo=ase, ~aska 99510 ~AU 212-24 ~. ~OCA~IO~ O~ W~ 10. ~ C~FERr Section 24, T 13 N., R. 10 W., SB&M and 50.44' . 1.1. SEC., T., ' O~E~IV~) ' ~ ' east at right angles Sec. 24, T. 13 N., R. 10 W., SB&M 1R ~I.~VATION~ f~how whether DF. R~_ ~. etc. 12. P~T NO. 77' GR J Check Appropriate Box To I,nc{~cate Nmlrure of NOtice, Report, or Other Da~a ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF j' J s~OOT OR AOID~E REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPI,ETE ABANDONs CHANGE PLANS ~Other) I~IUBSEQUENTREPORT OF: WATER SHUT-OFF [ REPAIRING WELL SHOOTING OR ACIDIZINO , ABANDONMENT* (Other) SDud (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR CO.%YPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. Commenced operations at 4:00 AM on August 19, 1973. AU,P, 2, 9 'i ,s "" '" i" ~-;!L AND GAS D{¥ ;c!,~ I', .... ANCHORAGE SIGNED ~//~t/'~ /.I _- W_ Wn I k~.r . (This ,pace foliate o~¢e TITLE Area Supervisor DATE 8-20-73 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See I,nstructions On Reverse Side Approved Copy Returned Form P--3 REV. 9-30-6 9 Sabrn~t "Intentions" in Triplicate & "Subseqaent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO, N COMMITI"EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR [~'Et%~iT-I~' 'for such 'pi:o~osal.~,) o., j--] 0AS [] WELL WELL OTHER 2. NAME OF OPE~TOR Standard Oil company .of C&liforniat WOI 3. ADDRESS OF OPERATOR P. O. Box 7-839 Anchorage, Alaska 9951.0 4. LOCATION OF %V~L At~urface 2000.46' South & 50.44' East 6~ the Northwest Corner Section 24; T-13-N; R-10-W; SB&M 13. ELEVATIONS (Show whether DF, ET, GE, etc. 77'Gr. 14. /5. AP1 N~CAL CODE · 6. LEASE D]/ISJGNATION A.ND SERIAL NO, ADL- 21128 INDIA.N. ALLO~I-FiiE OR TRIBE NAME 8. UNI~ FARNI OR LEASE NAME · Beluq~ Rive~ 9. V~LL NO. BRU 212-24 10. FIELD ~D POOL, OR WI~CAT Beluqa River Field 11. SEC., T., R.. M., (BOTTOM HOLE OBJECTIVE) Section 24; T13N, 12. P~dVIIT 1~O. R10W SB&M Check Appropriate Box To [nc!i'cate N, ature of N~ti'ce, Re, tort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDXZE REPAIR WELL PULL OR ALTER CASINO MULTIPLE COMPLETE ABANDONs CHANOE PLAMS · I Other ) r "j SUBSEQUENT REPORT OF: WATER SHUT-0,, J J REPAIRINO WELL _~_ SHOOTING OR ACIDIZINO ABANDONME~T' (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, ineludin~ estimated date of starting any proposed work. This well is to be treated as a confidential. ANCHORAGE (Thl. ~p&ce foi78tate office use) TITLE Area Supervisor APPROVED BY CONDITIONB OF APPROVAL, IF Ai~: TITLE See Instructions On Reverse Side DATE Approved Copy Returned AIg.~'l' 17, 1!)33 $~dI-4 011 ~ of Catl~la, Peflatt No. 73-t~ Mr. Staa4ar4 Oil P. O. BoxT-8~ AJmhofl~, AI~ Vm'y tl'dly yers, ~L.. ail'Ill ~i~ Al,tmk~ OII ami aI Ooaiir~ettm~ ~~ Form P~I REV. SUBMIT (Othe~, STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TTPE OF WORK DRILL J~J DEEPEN J--J O,L ~] WELL WELL OTHER 2.NAME OF OPERATOR Standard 0il Company of California~ 3. ADDRESS O~F OPERATOR SINGLE J-'-J ZONE W0I PLUG BACK MU I,TIPI,I: ZONE P. 0. Box 7-839~ Anchorage~ Alaska 99510 LOCATION OF WELL Als.trace 2000.46' South & 50.44' East of the Northwest Corner Section 24; T-13-N; R-10-W; SB&M At proposed prod. zone Same 13. DISTANCE IN MILES AND DIRECTION F~OM NEAREST TOWN OR POST OFFICE* Approximately 40 miles West of Anchorage, Alaska 6. ~ ~IG~A~ON ~ S~ NO. ADL-2112% 8, UNIT, FARM OR LEASE N~E Beluga River 9. WELL NO. BRU 212-24 10. ~ELD AND POOL, OR WILDCAT Beluga River Field 11. SEC., T., R., M., (BO~OM HOLE OBJECTIVE) 12. Section 24; T13N; R10W SB&M 14. BOND INFOR~IATION: TYPE Nationw~d~ and~or No. SL6205862 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST U n i t i z e d. S e e PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit. if any) a t t a c h e d ~ 1 a t 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 5280' See attached plat 21. ELEVATIONS (Show whether DF, RT. C-R, etc.) 77' GR. i 16. NO. OF ACRF_~ IN LEASE - 480~ 19. PROPOSED DEPTH 6000'+ A~o,,-t $150 , 000 ,_ t7. NO. ACRES ASSIGNED TO THiS WELL 640 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* August 20, 1973 23. PROPOSED CASING AND CEMENTING PROGRAM ' ' r SIZE OF HOLE SIZE OF CASIN(~I ,WEIGHT PER FOO~ GRAD~ SETTING DEPTH qUA~TIT! OF C~MI~N~ 26" r'20" 949 H-40 400'+ SOU _+ Cu. rt. ~; ~ 12 1/4" 9. 5/8 43.b~~ N-SO ~OOO'+ 13-1U + Cu. ~':. (Two ~tages~ ,, , , ~ , , , ~ ,, ,, ,, , We propose to drill subject well per the attached drilling program. ., Note: Per telephone conversation O.K. Gilbreth/W.D. Sauer, 8-7-73, we propose to transfer the approved application from BRU 221-26 to BRU 212-24. Approval may .be gained if applied for prior to the starting of drilling operations of BRU 212-24. Expected spud date for BRU 212-24 is August 20, 1973. IN ABOVE SPACE DI~SCR/BE i~ROPOSET) PROGRAM: If proposal is to deepen or plug back, give data on present p~oduetive zone and proposed new productive zone. If propo.sal is ~o drill or deepen direct 2onally, give pertinent data on subsurface locations and rneasu~d and true vertical depths. Give blowout preventer program. 9.4.1 hereby ce~..,~ th~jl~~e (This space for State office~ use) ISAMPLES AND CORE CHIPS B.EQI;I~) [] YES ~ NO j DIRECTIONAL SURVEY REQ~ [] YES )~NO NO_ u APPROVED ~¥ Correct . · . DATE ' ! /!~'t '~ -- lb? ja Supervisor CONDITIONS OF ~P~V~ I~ ~% ' ,~ ~ ', .f~ j j I I SEE · ~ I.~~, ~ Revere Side DRILLING FLUID PROGRkM BELUGA RIVER UNIT 212-24 BELUGA RIVER FIELD Basic System . Lightly treated Lignosulfonate mud. J~ptimum Properties Weight, pcf Viscosity, sec/qt, API Fluid loss, cc, API Plastic Viscosity, CPS Yield Point, lb.~lOO.ft.2 Gel, lb./100 ft. -10 min. ph Calcium~ ppm Solids Content, % volume Diesel Content, % volume Value Range To 13 3/8" Cng. Point 13 3/8" Csg. Pt. to 6,00p;~ 73-75 76-78 40-50 40-45 20+ 4-6 - ~ 10-15 - 5-10 - 10 max. - 8.5-9.0 - 50max. - 8-10 - 6-8 1. Chemically disperse mud with chrome lignosulfonate. 2. Treat calcium out as required. 3. Maintain adequate supply of lost circulation material and barite at the location. 4. .Run desander and desilter to keep solids at a minimum while drilling. 5. Increase viscosity while drilling surface hole as required to control gravel. 6. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. lO0 0 · $000 4. 00o · , GO00 2,Ooo 80oo 900o SHEET_ J_OF. J SHEETS .L ~-.. · --~ .... ~-.-t--~- ~'-- t i x-q-' ' ' ' ' ' ' ' ' ' ' :r.: - ' ' · ~-,~-h-f-1 ,-h!-l-h-~ ~H~--~-'~fl!-t-+-[Tf~ PROPOSAL FOR WELL OPERATIONS -LL~~4~4*~~-..--J-u~H.]4-,~m~-,.~ , .... .... ~: PROGRESS CURVE Pro-316-2 ~.H-,'.~-~ ~~ ~ '~ .... ' ' -' ' ~ ' ': ' ' '~-b~-; H.-.~ B. ~ U 2/2 -24 ........... . ~ ~ '. . ~ ~ ~' , ~ · , . ; ~~&~_~ ~~L~ ~.~ i ~ ~ ~I.L_. '-.; '-~-~--~4 ~--~----;--~-~ ~ ~ ; '4--44-~--~d't-~-w-H-~- , ,-., ~;---~F~ ~-'~ ,- ~ ' ' ' - ~ ' ~ ~ ~ : I T-- ~ ~ ~, I ~ I -- · -~-T-~-~' -~-~.-NH&-~ ~--*~~+¢-f--~- .+-¢-:-.r-¢~-~ f ¢-.~-r',-~-~.-H -r-~ .... ~H-H--H H' '--'~-~ 4-'f; · ~ , ' ~ ~ . I ~ . , / ~ ~ : , I , - , ~ ' ~ ' ' , ~ ' ~ I ~ ' ' .~ ~-A~-- · i I : I i~~t ~ ~ i , ~ ~ ~ ' ~ I I ~ : ' I : : ..... : : ~ x . ~ I ~ i t , , · : . ~ ~ ~ .... -'' 1: : T ~ - :-' I I ' , '~1- ~=~' : : '' I..' : ' ~ [- , j , ~, : -~- · . ; , ~ r , 1 ~ -T - I ; '' J i ' ,-If ': : ~ i ' ,- ' i ...... , ' ' ~ t ; :-i .... , ~ , i , , . C'~' - '' ~ ' i ~ '-- -- '...; ~ ~' ' t ,iL i "- .--~. -..,~ .... ' , t ' _ _' ~ . '. , ._;...;_.' ,~ . , , ,? .+~ . ,,. :..~4 ~: , ~ :,tl,T , . ,_ ~_ ', . , +. . , , _ , ..... ..... ~ .: ~,,-. -~ . + -.-.-.~ ......... r ~ ' ~ ~ ' -~' "' ' --'- ~ ' ~ ~ ~ ' F ' ~ ....... -3--7~-~ ,- T~F. , , N- i T~~!--~Z-~ .. ~-~ .... I--~-~ :-m--~'~-- ~' r'~:Z~L/P~ ~ .~:4~ --~'-f~hN-t'- r-t ~. t,--~ ~~-f-?~-.-~-f~-~-?~~~ ~' y1-T-"T~'''~ .., , , , . , .. , : ....... ~ . __ ~ '_ .I__LL'4 '.A-.'.-'4--: .... ,_, L~ ....... , ' . ................. ~ .... PROPOSAL FOR ~ELL OPERATIONS PRO 316-1 DRILLING PROGtLAM FIEL. D: BELUGA RIVER PROPERTY AND ~LL NO.: BELUGA RIVER UNIT #212-24 LOCATION: Approximately 2,000' South and 50' East of the Northwest corner of Section 24, T. 13 N., R. 10 W., SB&M. ELEVATION: Estimated K.B. is 105'. BLOWOUT PREVENTION CONSIDERATIONS 1. Potential Problems: Gas: The proposed well is a development location in a known gas field. Numerous gas sands will be penetrated during the course of drilling this well to total depth. Gas entries into the mud column can cause serious problems. Care must therefore be exercised at all times to prevent these entries by either swabbing the well when pulling pipe or hydraulicing the formation (with associated lost circulation) on trips. Rapid penetration rates cause an increase in mud weights and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause serious problems. The beds contain some gas, slough readily, and drill rapidly. If thick beds are encountered, reduce the penetration rate and/or circulate bottoms up. Extreme care must be exercised in the drilling of these beds since they slough, and cuttings tend to pack off around the bit. This pack- off can cause"~i6~Bt circulation, kicks and a stuck drilling string. L__ost Circulation and Water Entries: Lost circulation is believed to have been the cause of the blowout at BRU 212-35 (#1 discovery well.) Too rapid a penetration rate caused an overloading of the mud column with cuttings followed by lost circulation and gas entry. The most recent well drilled at Beluga, BRU 241-34, was drilled to 6501' with 78-80 pcf mud There were no gas kicks, lost circulation zones or zones of water entry. Penetration rates were limited in the top hole. Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods Care should be ised at all times y .... ry exerc ~ L~i member of the crew. The hole must be kept full at alum ~a ~i~ ~ ~ ~ ~ ~ lyf.' ANcH~RAO~ PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM. BELUGA RIVER UNIT BRU #212-24 -2- 2. Estimated Depths and Formation Pressures: (Based on 0.47 psi/ft, gradient) Zone or Marker Drilled Sub sea Estimated ~ ~ Pressure ps__i Top Sterling "A" Gas Interval Top Beluga River Formation T.D. 3180' -3075' 1500 3640' -3535' 1710 6000' -5895' 2820 3. ~£aximum Anticipated Surface Pressure: 3,000 psig. 4. Blowout Prevention E~: · a. 20' - 2,000 psig, Class II B on the 20" casing. b. 12" - 3,000 psig, Class III & Shaffer Rotating Blowout Preventer on the 13 3/8" and 9 5/8" casing. c. Installation and testing of the above equipment is outlined in Operating Instructions D-17. OBJECTIVES: Sterling and Beluga River formations. PROGRAM 1. Drive 30" conductor pipe or cement 36" corrugated culvert pipe at 10'~ below the base of the cellar floor. 2. Drill for 20" casing to 400'. Maintain drilling fluids per attached Drilling Fluid Program. 3. Cement 20", 94#, H-40, Buttress casing at 400% with 430 sacks of Class "G" cement premixed with 2.4% gel, by weight of water. This provides a 33% excess cement volume. If cement does not return to surface, do a top job. a. Cement-Gel Properties: Yield: 1.86 cu. ft. slurry per sack cement Slurry Weight: 97-98 pcf Water Required: 1.38 cu. ft. per sack cement Gel Required: 1.5# per cu. ft. of water At.~,cHORAGF~' c PROPOSAL FOR ],tELL OPERATIONS PRO 316-1 DRILLING PROGRAM BELUGA RIVER' UNIT BRU #212-24 -3- b. Use a Baker Duplex shoe with Sta~-in connector. c. Bakerlock casing and shoe. d. Centralize casing over the entire 400'. Install Class II B BoPE on the 20" casing per attachment. Nipple up blow and kill lines, and manifold for 3000 psi service. A Class III, 3000 12"- psi BOPE with a Shaffer Rotating Blowout Preventer will be installed later. Test BOPE per Operating Instructions D-17. NO___T__E: Burst pressure for 20" 94#, H-40 casing is 1530 psi with no safety factor. Do not exceed a 1000psi test. 5. Drill out cement and drill ahead in 12 1/4" hole to a dull bit near 3100' COndition mud and hole for logging. ' NOT~E: a. Limit penetration rates as necessary to maintain optimum fluid weight and solids c°ntent. b. Install Mud Logging unit at approximately 400' and collect samples every 30'. 6. Run and tape the following logs using Schlumberger equipment. Ail logs are to be run from total depth to the shoe of the 20" casing. Take a 1/2 gallon drilling fluid sample immediately prior to pulling drill pipe for logging. a. Dual Induction - Laterolo~ 2"=1.00' - Arithmetic, Resistivity 0-50 ohm meters and ~10 mv SP scale. 5"=100' - Logarithmetic, Resistivity 0.2-2000 ohm meters and +10 my SP scale. - b. Combination Compensated Neutron - Densi~L_0~% Density scale 2.0 to 3.0 grams/cc. Neutron scale of -15 to +45 sandstone porosity units. Gamma-ray and. caliper curves are to be recorded in the left-hand track. 7. Drill ahead in 12 1/4" hole'to the top of the gas productive Sterling sands, (depth equivalent to 3338'-in well BRU 212--25) as estinmted from the dual induction log and the mud loggers. PROPOSAL FOR WELL oPERATIONS PRO 316-1 DRILLING PROGRAM BELUGA RIVER IP{IT BRU #212-24 -4- 8. Cement approximatelY 3180' .of 13 3/8", 68#/ft., K-55 Buttress casing on bottom with 1780 sacks Class G cement premixed with 2.1% Gel, by weight of Water, to reach the surface. This provides a 33% excess cement volume. If cement does not retUrn to the surface, do a top job. a. Cement-Gel Properties: yield: 1.68 cu. ft. slurry per sack cement. Slurry Weight: 101-102 pcf Water Required: 1.16 cu. ft. per sack cement. Gel Required: 1.3# per cu. ft. of water. · b. Use a Baker float shoe and Baker Duplex collar with stab-in connector. c. BakerlOck the bottom five (5) casing joints. d. Use centralizers.at, and above the casing shoe and in the 20" casing. 9. Cut off the 13 3/8" casing-to allow top of tubing head to be above ground level upon completion. Install 13 3/8", 12"-3000# top flange, SOW casing head. Test welds to 2500 psig, 10. Nipple up 12"-3000 pSig Class III BOPE including Shaffer Rotating Blowout Preventer per Operating Instructions D-I7. Connect blow and kill lines. Pressure test all BOPE to rated pressure per Operating Instructions D-17. 11. Drill out cement in the 13 3/8" casing to within i0' of the float shoe. Run Variable Density Cement Bond Log from effective depth to the 20" casing lap. Make water shut-off tests as required. 12. Drill out cement and drill ahead in 12 1/4" hole to dull bit near 6000'. Condition mud and hole for logging. a. Consideration will be given to spot coring selective intervals in the Sterling and Beluga sands. b. Limit penetration rates as necessary'to maintain optimum fluid weight and solids content. Circulate out drilling breaks or reduce penetration as directed by Standard Oil Company Drilling Representative. 13. Run and tape the following Schlumberger logs at the effective depth. Obtain the drill pipe to a 1 2 gallon sample of the drilling fluid prior to pulling PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGP, A~{ BELUGA RIVER UNIT BRU f~212-24 -5- a. Dual Induction-Laterolog: As listed above. b. Combination Compensated Neutron-Density Log: Same scales as listed above. c. Borehold Compensated Sonic Log: Use 50-150 microsecond transit time scale. SP and caliper are to be recorded in left-hand track. SP ~10 mv scale. d. Proximity Log-Microlog with Caliper: Use logarithmetic resistivity scale of 0.2 to 2000 ohn-meter; micro normal 2" 0'20 ohm-meter; and micro inverse l"xl", 0-20 ohm-meter. · e. Run four arm HR dipmeter and record using both analog and magnetic tape. f. Be prepared to run sidewall samples. 14. Cement approximately 6000' of 9 5/8", 43.5#/ft., N-80 8rd LT&C and Buttress casing on bottom in two stages as follows: a. Run float shoe and float collar. Run one stage collar placed approximately at the base of the Sterling sands now estimated near 3500'. b. Bakerlock the bottom 5 joints of casing. c. Centralize the casing throughout the productive intervals. d. Cement the 9 5/8" in two stages as follows: 1)Stage 1 through the shoe using 670 sacks of Class "G" neat cement. Use no excess. (Fill calculated from 6000' to 3500'). 2) Through Stage collar'at 3500+with 500 sacks of Class "G" neat cement. Fill calculated to the 13 3/8--" shoe plus 1000' into the 13 3/8"x9 5/8" casing annulus and includes 33% excess cement on the open hole portion. 15. Land the 9 5/8" casing. Install 12"-3000# x 10"-3000# tubing head and secondary seal assembly. Test secondary seal to 3000 psig. 16. Nipple up 10"-3000 psig Class III BOPE. Install kill and blow lines per attachment. Test BOPE per Operating Instructions D-17. Test lines to 3000 psig. 17. Further program to follow, including CBL, perforating, and possibly a formation test based on log and test evaluation, a completion pro~ W. R. TINKER III W. D. SAUER ANCHORAGE DRILLING FLUID PROGRAM BELUGA RIVER UNIT 212-24 BELUGA RIVER FIELD ~stem Lightly .treated Lignosulfonate mud. Optimum Properties Weight, pcf Viscosity, sec/qt, A~I Fluid loss, cc, API Plastic Viscosity, CPS Yield Point, lb ~100 ft.2 Gel, lb./100 fti~-10 min. ph Calcium, ppm Solids Content, % volume Diesel Content, % volume Value Range To 13 3/8" 13 3/8" Csg. Pt. to ,0001 73-75 40-50 20+ 76-78 40-45 4-6 10-15 5-10 10 max. 8.5-9.0 50 max. 8-10 6-8 REMARKS: . . . . 5, . Chemically disperse mud with chrome lignosulfonate. Treat calcium out as required. Maintain adequate supply of lost circulation material and barite at the location. Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drilling surface hole as required to control gravel. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. :'*- ' ~ '~- IfELL'*' SURVEY Pro-312 i" YELL NO. ,B, RU 212-2,4 , ' COU#T¥. OF CITY OF. ; SECTION NO._ 24 _ _TOWNSHIP -13 N RANGE_ 10 W D S.B.~I. & H. EZ] H.D.B. & 14. , TRACT NO., LOT NO..,.i FI ELD * I~B PItOPOSED } 2,000,~46 feet ~South of N.W. corner. Section 24 T13N, 121 PREI. I141NI~ LO.CATI ON RI OW ~ Seward Meridian~ Al, aska~ and 50.44 feet East at riqht. I~ F~.~I. an,q I es 50.44' Lo':;e~-i~,, .... u~+^r,, ~ ~ ELEI/ATIOH: GROUND 77.3 Datum .Mean COlCCRETE HAT DERRICK FLOOR ........-' ' A L T E R N'A'T E O R .:'$ u R v E.Y £ ' D L O ' c A T ~ 0 N rq ~ ,, --LOCATION' 'l' ' LOCATiON.COORDINATEs* . HoVE ...':i * 'REHARK$ DESIGNATION · ... . · .' ,. Final· X:.323,388 12' Y: 2,633~629.68 Center of Well Cellar. , . , ,, : .. , , . . · · . . , · :'. : ..'. .-.. ~ '.'"-;~ · . ' . . . , NORTH -... . . .:. SKETCH OR REI, AARKS ' .. ~ ' ,, . .' .'.. - . . -. . ~...~ ', .,. 1. I Locatio~ _is .to center of existing' ._~_,~___ ~,_,+____ I'. ] well'~cellar... . ~.~...~.,'"" ~',..~d?,,~~'~ '' '1 ''':~ I*~-'.: · '' '. ' :~.. c°°rdinates, are'Alaska state. ~:',49~~ Sec,124 :~] -., . .Pl'ane,. ,'-:,.Z°ne . , .4' .. . .. ''' ~'~ C, ~ ,""" '"'"' "'"0' 'l -"-. !'. Vertical datum is to mean lower ~..'~ N0.813-S -~-'-T ~1" ' low water. ' . ~t '~..~ I .,- :. . .. .' ' SOUTH '"' "' Is: ~f rim of'metal cellar, East side of well. Elevation - 77.28 · STATION . BEARING * - DISTANCE ' s INE COSINE NORTH ~OUTH F...AST WE:ST . ...... - , . , ,,,. . . .,. ..... ....... . ' . ~. k~ ~ ~ I' " ' '" - ,.t~,, ~ A~, · E IV-Ri<,ii .... i. ""' . · - . '.. ' . · · ~ . ..~. . . . . . . , _ . , , · . . . . ,,. ~.,, ,, , ~ , , C,C, OlV, ENGR. FIL~ DATE Auqust 2. 1973 DATE NAINT. SUPT, DATE Form P~3 iSubrnit "Intentions" in Triplicate ~ ,~, \,.~ _ ~ __.. STATE OF ALASKA A~GAS CONSERVATION COMMIITE~: $. AND REPORTS ON WELLS N "~. ~or proposals to drill or tO deepen ' ,"APPLICATION 'FoR ~'EP,.~iT~-~' 'for such .... AP1 NU-M.F-,Ii/CA.L CODE 50-283-20037-00 LEASE DESIGNATION AND SERIAL NO. ADL 21127 1. OIL C OAS WELL WEL 2. NAME OF 3, ADDRESS OF P . O. BOXy' 7. IF INDIA.N, ALLO'i"rI~E OR TRIBE NAME OTHER 8. 7 39 Anchorage, Alaska 99510 4. LOCATmNOFW~L Atsurface Apprc East of the N, T-13-N;R-10-W imately 660' South and 1980' hwest corner of Section 26; ~M 13. ELEVATIONS (Show whether DF, 105'+ K.B. ,4. Check etc. Box To }nd}cate N, ature of NOtice, Re UNIT, FARA~ OR L~SE NAME Beluga Ri~er V~ELL NO, BRU 221-26 10. FIELD ~D POOL, OR WI~CAT Beluga River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 26; T-13-N;R-10-W SB&M 12. PElq2VIIT I~O. 72-15 2ort, or Other D~ta ' NOTICE OF : TEST WATER SHUT-OFF { { PULL FRACTURE TREAT ~__~ M ULTIPL! SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHAN0~ ~Other) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clear[ proposed work. CASINO OMPI,ETE SUBSB2qU~NT R~PORT OF: W&TSR SHUT-OFt {1 { [~ I R~PAIRINO W~LL FRACTUR~ TReATMeNT ~ ~~ ALTERING CASING SHOOTING OB AC[D[Z[NG ~ ABANDONMERTs (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) tate all pertinent details, and gh.e pertinent dates, including estimated date of starting Any Confidential Standard Oil Company of Californ of BRU.well 221'26. A notice of We'proPOse the' change because a 21 northern limits of the. field.. Pert: has been included above. Wepropose location: Approximately 2000' south and 50, Section 24; T-13-N; R-10-W; SB&M. A drilling'Program outlining how.we · proposes to '.drill well 'BRU 212-24 in lieu to'drill 221-26 was approved in 1972. -24 location will better define the data regarding the 221-26 location 'BRU 212-24 at the following of the northwest corner of to'drill this well is attached. · Drilling isscheduled to commence approximaJ take 30 + days. 16. I hereby ce~th~t Che f.oreso~ is true and correct (This space/or :tate o~ce 111; !ly .August 15, 1973, and will Ab',CHORAG~ APPROVED BY CONDITIONI OF APPROVAL, IF AI~: TITLE DATE DATE See I, nstructions On Reverse Side /l~prov. ed Copy Returned August 3~ 1973 Re: Belu§a River - BRU 22t-26 I~'. J. W, Walker Standard Olt Co. of Ca I t fora I a P. O. Box 7-839 Anchorage, Alaska 99500 Dear Mr. Walker: Enclosed we are returning the attached P-~ fo~ :because ~ cannot frans the approved application f~om ~ 221-26 to ~ 2t2-24 ~u:~ t~ ney ~ I les In a different spacing unit. Please submit a P-I form fo~ t'he ~ well. ~/~-.= , SI nceret¥. Tho.ms R. Marshal I, Jr. Chief Petrolea~ Geologist T~:pj Chevron Standard Oil COmpany of California, Western Operations, Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 J. W. Walker Area Superintendent Producing Department July 10, 1973 Plan of Operations For'Drilling Beluga River Unit Well 212-24 Mr. Homer:Burrell, Chairman Alaska Oil and Gas Conservation Committee Department of Natural.Resources 3001 Porcupine'Drive Anchorage, Alaska 99501 'Mr. Rodney Smith Regional Oil and Gas.Supervisor Alaska Region U. S. Geological.Survey P. O. Box 259 Anchorage, Alaska 99510 .Gentlemen: The.attached Plan of Operation covering the forthcoming drilling of'BRU Well 212-24 is for your files and infOrmation. Attachment ~Very'truly yours, ~. Walke'/~N~/ 'Chevron Standard Oil Company of California, Western Operations, Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 J. W. Walker Area Superintendent Producing Department Division of Lands Department of Natural' Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 Attention: Mr. Pedro Denton July 10, 1973 Plan of Operations For 'Drilling Beluga River Unit Well 212-24 DIVISION OF ©~L AND OA~ ANCHORAG, E Gentlemen: Standard Oil Company of California, on behalf of itself, Atlantic Richfield Company and Shell Oil Company, plans to conduct drilling operations within the'Beluga River Unit during the summer of 1973. In order to carry out and 'provide logistical support for the proposed operations, it is necessary for us to obtain your approval of our Plan of Operations, a gravel permit 'from your Department and approval to use the old Superior Docking Area (ADL 45327), now reserved by the State. 'In.support of our requests, bhis letter will catagorize and describe the different.items that we understand you wish to know. 1. .Well site and .Setting .The proposed ~ocation for Well 212-24 is approximately 2000'S and .50rE of the NW corner of Section 24; T-13-N; R-10-W SB & M. A new .permanent'gravel pad will have to be constructed at the proposed site. About 3' to 4' of tundra covers the underlying gravel and this will be cleared in the area of the site including the mud waste pit. Excavation material'from the pit will be used for a portion of the location gravel. Additional gravel may be needed for the pad and will be needed to build approximabely 2500' of a new access road from an existing road. This · gravel will be removed from an existing borrow pit located approximately % of a mile'from the proposed start of the new access road. It is estimated that a total of 35,000 cubic yards of new gravel will be required for pad and road construction. An application for a gravel permit is attached. A plat is also attached showing the location of the'proposed pad, road and existing gravel pit. .The proposed pad and access road will be constructed in and through a wooded area. For construction of the well pad and road, the minimum amount of'trees will be cut down. ~2.'-Existing Roads and Airstri~ . Ail roads in this area from the Superior Landing to the South to the Ivan River 44-1 Well to the North were built in the 1962-1965'era by Standard Mr. Pedro Denton Department of Natural Resources -2- July 10, 1973 Oil Company of California as operator for the Beluga River Unit as well as during the course of other Exploratory activity. The proposed 2500' access road to the proposed BRU 212-24 location will be a spur road from one built during 1965 in support of Exploratory Well Ivan River 44-1. The pit proposed as a gravel source for Well 212-24 was also used as a source to build the existing road in 1965. The Beluga River Airstrip was constructed during the 1962-63 original field development. It will also be used in support of our proposed 'drilling operations at BRU 212-24. 3. Water Supply A new water source well will be'drilled at the location to support .our-drilling operations. 4. -Drillin~ Rig. ~ We are currently negotiating with Brinkerhoff Drilling Company and ~. B. Montgomery Drilling Company for use of either Rig #59 or #33, respectively, to'drill.our proposed well. No commitments have been made to date. 5. .Access to Site and Method of Su~ly The site is remote and is not connected to the Anchorage area by road. The'.only.access is by one or more of the following: A. BARGING TO THE SUPERIOR LANDING (STATE RESERVED AREA ADL 45327) .Du~ing most of the year barging is possible from the Kenai or Anchorage area to the Superior Landing and thence by truck to the · proposed wellsite. Use of this Landing will definitely be required to drill the proposed well. Should the Brinkerhoff Rig #59 be used to drill this well, it will be necessary to barge it to the Landing. It may also be necessary to barge out the rig after drilling is complete. NO matter which rig is used, most all of the materials and.supplies required to drill this well will have to be barged to the.Superior Landing. We request permission to use the Superior Landing. Although plans 'are somewhat indefinate due to rig availability, we estimate oper- ations should commence around August 1, 1973 and could continue intermittently throughout the summer and fall to approximately .December 1~ 1973. B. AIR TRANSPORT TO BELUGA AIRSTRIP The Beluga Airstrip was worked on and made suitable for Hercules type air transport in 1968 when a complete drilling rig was moved Mr. Pedro Denton Department of Natural Resources -3- .July 10, 1973 to the North Slope from the strip. It has been used on occasion by the same size aircraft and we intend on using this method to move freight and other items as can be justified economically. Since the rigs available use diesel fuel, we will probably fly in the fuel. Sufficient hard tankage is available to eliminate consideration of "bladder', tanks. A 50,000 gallon fuel dump will be established at the Beluga Airstrip at the same-location as existing facilities installed in 1962. 6. Personnel Support Since our drilling operations should be conducted during the summer .period, we do not plan on establishing camp facilities. At this time .we plan to make'drilling crew change by air on a 12 hour basis. The morning and evening time for this change has not been established and is'subject to negotiation with the drilling contractor. Definate work schedules will be established for each segment of the working force so change-outs can be done on a scheduled basis every day to eliminate any conflicts with other contiguous operations. A trailer for the Contractor's and Standard's Supervisory personnel will be installed at.Beluga. · 7. Miscellaneous Related~Drilling Items A.. The waste~pump'will be located, constructed and diked as necessary to prevent the possibility of any seepage to the surrounding terrain or'drainages. Upon completion of drilling activities, the waste pit will be filled, leveled, fertilized and reseeded with natural grasses. B. Sanitary facilities consisting of a covered.waste pit will be con- structed. This will be 'covered and backfilled upon completion of the work. .'C. ~ThelProposed location is approximately 800' from the nearest pond. ~Our proposed drilling operations should not distrub this area .whatsoever. 8. Other Construction on the Site Well BRU 212-24 is a.development location and commercial production should be encountered. This well is being drilled to aid in the determination of the field reserves and productive limits. There is no immediate market for the gas volumes expected because our existing wells to the South haVe the capacity to supply our contrac- .tual requirements to Chugach Electric Association. Accordingly, Mr. Pedro Denton Department of Natural Resources -4- July 10, 1973 production facilities will not be immediately installed. When they are installed, the production, dehydration, and metering facilities on-site will be similar to those already installed for the six existing producers. Some minor inner-connecting line chang'es may be required. At present we plan to dually complete the well with two producing strings. 9. General Comments A. No unnecessary surface digging will be allowed. In the past we have restored construction areas and taken measures similar to the rehabilitation methods used at Swanson River. In this case, if .sufficient need exists after the proposed work is completed, we intend to.fertilize and reseed as necessary with natural grasses. Regrowth in the Beluga'Area is rapid and does not appear from past experience to require much help except fertilizer. B. Combustible wastes such as mud sacks, etc., will be burned in the location, while other hard wastes such as drilling bits, etc., ~will be disposed of in the waste pit when it is closed and covered after 'drilling is finished. The items covered above should answer any questions regarding our plans for conducting surface operations in connection with Well 212-24. If you have .need for further clarification, please detail these and we will attempt to 'provide answers. .Very truly yours, J. W. Walker .Attachments :1) .Beluga River Area Plat 2) Beluga River 'Area Map ._ ~ ·., CC: 'Mr. Robert.Weinhold/Department of Fish & Game, Habitat Section 1 M ~TANDARD OIL COMPANY OF CALIFORNIA 7J:.~.,..,. :Z~l[ 'i'", .-wESTERN. . OpERATIONS, INC.. ..I}:-D~::~"/--~(')'"ZL:. : '.' L.:{ ,-' :_." :.,/' ~-.-z..~4 .... : -:,i , .. ' (OPERATOR) " [ P.--:-~-- .......... ;_.. ....... · ........ : ....................... ....... .,.J ........ [~$:;Aca': t'= /00::' . /04;c;~ 7-:~--73: '7"/.~:,~' ~:',,-.>iv' ~,.L:"..' i.., ~ ', ....... m''...'...,;~ A ' . , ; ' ' :' ., "" £~lese~t ts the Wl~rov~t ~pplt~tlo~ ~ p~m, l t to ~rl I t tl~ ~ referenced ~II ~les a~d ~ ¢l~ips ~ .~rt ~tr~d nor Is a dlr~.-tlonal survey. A ~:lftll<t:-SUr~/o~'*$ plat :Is ~l:~;lH~, h:0~ev~r. Na~y rivers in Ai~ ~ their ~tn~ systems have been classified ~ i~~ for ~e sp~l.g ~ ~9r~l~ of .~a~ fiji. ~~tl~ 1~ ~e a~~ ~ s~~ ~ ~ t6..05.~ ~d ~ ~t~1~ p~tga~d ~e~- ~r ~ltte ~, AI~ ~nls~l~ ~),. Pri~ to ~clng ~rati~ y~ ~ be ~t~d by t~ ~ttat ~rd-in.a~r*s offl~, ~p~f of Fish in the eveat of sus~ton or .~amdeeme~t please give fhls offl¢~ ad~uate ~~ ~ottfl~flon ~ that we ~ have a wlt~m~s present. Enctesure ~~t of Ft~.~ ~d ~, ~lht ~¢tt~n v/o e~ct. ~a~~ of ~-v!~montal ~se~vattoa ~/o ariel. , (Other ,nstructlo .} C .... ''_ ¥ot~,'.-, P--I reverse side ~'"~ SLATE OF ALASKA APl NO. 50-28~-2, ,~1~~. , OIL AND GAS CONSERVATION ,COMMITTEE' ADL 2~27 ~ ~'~w-'f '- -APPLICATION. FOR PERMIT T0 DRILL, DEEPEN,. OR' PLUG BACK ~. ~ ~.,~o. ~~..,Ol4 m°l ....... DRILL ~ , DEEPEN ~. PLUB BACK ~ b. TYPI OF WILL . 8,NGL, ~ MUI.TIPI.' E] 8.' UNITtFARM OR LEASE N;,~j''-~' ~F~I. ST~DA~ 0~L C0~ 0F CAL~F0~A, ~STE~N 0~g~T~0NS, ~NC. ,. w~o. ~ R~V ,, ir ~. ADbR~OP~R BRU 221-26 J' AEC ..... P. 0. ' Box 7-839, ~chorage, Alaska 99510.. ~0. mzug a~u J,c,o~.'oa ;~ ~~[ , 4.' LOCAT~ON'O~ WELL · ~ Beluga Rive atsurface approximately 660_ souCh and 1980' eas~ of norck~e.sC~ . corner, Section 26, T. 13 N., R. 10 W., S~ , ~,.SZC..T..a..~..,~O~O;,~ - - HOLE OBJECTIVE) atpr0~seaproa, zone approximately 660' south and 1980' east of north- Section 26, T. 13 N., west comer, Section 26, T,13 .N, R. 10W, SB~ R. 10 W.. SB~ 13. DISTANCE IN MILES AN~ DIRECTION ~flOM' NEA'RES/F'TOWN OR POST OFFICE* . 12. . . . Approximately 40 miles west of...~chorage. ........ 14. BOND INFORaMATION; ?YPE Nation Wid~rety a.d/or ~o. SL 6205862 DISTANCE FROM PROPOSED' Unitized, see LOCATION TO NEAREST attached PROPERTY OR LEASE LINE. I~T. p±a~. (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST %VELL DRILLING, COMPLETED. OR APPLIED FOR. FT. +41'00', see attached plat 21. ELEVATIONS {Show whether DF, RT. C-R, etc.; Approximately 110' K.B. i 16. NO. OF ACRES IN LEASE ' ' '480 acres '9. PROPOSED DEPTH +6000' 23. PROPOSED CASING AND CEMENTING PROGRAM ~o,,-t $150,000 .... 17.' NO. ACRES ASSIGNED TO THiS WELL 640 acres 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX, DATE WORK WILL START* August ~. 1972 . , SIZE'OF HOLE SIZE OF CASING ,WEIGHT PER FOOT GRADE SETTING DEPTH QL'A,,N, TITY OF CEMEN'~ : 2'6'" '" 20" 'r 94 H-40 +400' +700 sacks ' 17 1./2I' 13' 3/8"' i 61 K-55 ~2700' ~2000 sacks '"' 12 1/4" 9 5/8" 43.5 N-80 ~6000 2 sta~es' +1525 sacks ? . , , , , ,,,, , , , _ We propose to drill the subject welI per '~the attached drilling program. IN ABOVE SPACE DESCRIBE I~ROPOSED PROGRAM: If proposal is to deepen or plug back. give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen direct _onally.. give pertinent data on subsurface l~.Ations and measttz~d and true vertical depths. Give blow. ut preventer program. DATE wrrnz Distri,¢~ Superintendent (Thi~ space for State .office use) CONDITIONS OF APPROVAL. IF ANY: O.y~S ~NO SEE TRANSMITTAL LETTER jDI~RECTIONAL SURVEY RE~ A.P.I. NIJMZ~CAL CODI~ . ' *~ I.~on, ~ Reve~ Side PROPOSAL FOR WELL OPER~-~iONS PRO 316-1 DRILLING PROGRAM, WELL BRU 221-26 Page 2 ,. 2.' Anticipated Formation Pressures: Zone Top Sterling "A" gas interval Top Beluga River formation Base Known production Total Depth (based on 0.47 psi/ft, gradient) ~pproximate Drilled DepLt.h ~ressure, psig 3000' 1400 3400' 1600 5200 2450 6000 -2800 3. Maximum Anticipated Surface-Pressure: 2500 psig. Blowout Prevention Equipment: a. 20"-2000 psig, Class II B on 20" casing. b. 12"-3000 psig, Class III and Shaffer Rotating Blowout Preventer, on the 13 3/8" and 9 5/8" casing. · · Sterling and Upper Beluga River formation sands. Program 1.: Cement 36" corrugated culvert pipe at 10'+ below the cellar floor. 2. Drill for 20'" H-40 casing to +400'. Cement 20" casing on bottom with sufficient Class "G" cement to reach surface. 3..- Install Class II B BOPE on 20" casing. Test as directed. 4. Clean out cement and drill 17 1/~- hole to dull bit near 2700'. 5. Run and tape the following logs using Schlumberger equipment. a. Dual-Induction-Laterolog from total depth to the shoe of the 20" cas lng. b. SP-BHC Sonic log from total depth to the shoe of the 20" casing. ,, 6.. Cement 13 3/8" casing at a depth equivalent to 2800' in Well BRU 233-27 with "sufficient Class "G" cement to reach the surface. PROPOSAL FOR WELL OPEP~. ~oNS PRO 316-1 DRILLING PROGRAM, WELL BRU 221-26 Page 3 7. Install Class III BOPE and Shaffer Rotating Blowout Preventer on the 13 3/8" casing. Test as required. Pressure test 13 3/8" casing to 2500 psig. 8. Drill out the 13 3/8" casing shoe. Drill ahead in 12 1/4" hole to dull bit near 6000'. Note: Depending on degree of structural advantage of 221-26 over 233-27 a drill stem test of the Upper Sterling sands may be made. 9. Run and tape the following'logs, using Schlumberger equipment. Ail logs to be run from total depth to the shoe of the 13 3/8" casing. a. Dual-Induction-Laterolog. b. SP-BHC Sonic log. c. Gamma-Ray-Compensated Density log. d. Four-arm High Resolution Dipmeter. Note: Depending on structUral position and advantage, consideration will be given to deepening this well to the "D" sands of the Tyonek form- ation, approximate depth 10,800'. 10. Cement 9 5/8" casing at the effective depth in two stages using Class "G" cement. Cement through shoe with sufficient cement to reach the stage collar Place stage "' ' a un= . co-ia~ t ..... base of the" ............. ~' ~ ~vw=~a~t F~uuc~ve Sterling sands. Cement from stage collar ~to"laP into the~'13 3/8" x 9 5/8" annulus. 11. Install Class III BOPE. Test BOPE as directed. 12. Drill out cement and 9 5/8" stage collar to top of 9 5/8" float collar. Pressure test casing to 3000 psig. 13. Run CBL and test for WSO as directed. 14. A detailed completion program will be provided after the final log run. The proposed completion for this well will be a triple string with the long string to produce the Beluga River formation and the two remaining strings to produce the Sterling sands. ' W. R. TINKER III/W. D. SAUER PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM Field: Beluga River Prop~erty_ and Well No.: Beluga River Unit ~/221-26 Location: Approximately 660' south and 1980' east of the northwest corner of Section 26, T. 13 N., R. 10 W., SB&M Elevation: Estimated K. B. is 110' Blowout Prevention Considerations: Potential Problems: Gas: The proposed well is a development well in a known gas field. Numerous gas sands will be penetrated during the course of drilling this well to total depth. Gas entries into the mud c61umn can cause serious problems. Care must therefore be exercised at all times, to prevent gas entries by either swabbing the well or hydraulicing the formation (and associated lost circulation) on trips. Rapid penetra- tion rates cause an increase in mud weights and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause serious problems. The beds contain some gas, slough readily and drill rapidly. If thick beds are encountered, reduce the penetration rate and/or circulate bottoms up. Extreme care must be exercised in the drilling of these beds since they slough and cuttings tend. to pack off around the bit. This pack-off can cause lost circula-_ tion, kicks and a stuck drilling string. Lost Circulation and Water-~Entries: Lost circulation is believed to, have been the cause of the' blowout at BRU 212-35 (~1 discovery well). · Too rapid a penetration rate caused an overloading of the mud column with cuttings followed by lost circulation and subsequent gas entry. The most recent well drilled at Beluga, South Beluga River Unit f~14-3, was drilled to 10,000', with 76-78 pcf mud and from 10,000'-13,000' with 80-82 pcf mud. There were no gas kicks, lost circulation zones or zones of water entries. Penetration rates were limited..in the top hole. Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. CHECK !. IS!' FSi'( NEW ~?!i~ '£RMITS Yes No Remarks, l. Is well to be located in a defined pool ................. ~. ~o state-wide rules apply ........................ .~/~o~ -registered survey plat attached .................. 4. Is well located proper distance from property line ........... ~ ~Is well located proper distance from other wells ............ ~.'~. 6. Is sufficient undedicated acreage available in this pool ........ h~c 7. Is well to be deviated ......................... 8. Is operator the only affected party ................... U ry.77~ ~ r~ g. Can pemit be approved before ten-day wait .......... ' ..... , Does operator have a bond in force ................... ll. Is conductor string provided ..................... )~. Is enough cement used to circulate on conductor and surface ..... ' '/~1/-- ,.. I x\Wtll ce~nt tie in surface and intermediate or production strings . . . 14. Will ce~nt cover all possible productive horizons ........... 15. Will surface casing cover all fresh water zones ............ I6. Will surface csg. internal burst equal .5 psi/ft~ to next string . . '' uJ.~ i,'. 17. Will all casing give adequate safety in collapse and tension .... ' 18..Does BOPE have sufficient pressure rating ............. Addtttonal Requ i rements · Company ~-~. © L_ Lease & Well NO. CHECK LIST FOR NEW WELL PERMITS Yes No Remarks Is well to be located in a defined pool ................. __ ~,//-~x~ Do statewide rules apply ........................ _ Is a registered survey plat attached .................. ~- Is well located proper distance from property line ........... x~ Is well located proper dis. tance from other wells ............ Is sufficient undedicated acreage available in this pool ........ I s wel 1 to be deviated ......................... __ ~y~ Is operator the only affected party ................... Can pe~it be a~proved before ten-day wait ...... Does operator have a bond in force ................... · - I. Is conductor string provided ...................... _>. Is enough ceme~t used to circulate on conductor and surface ...... ). Will cement tie in surface and intermediate or production strings ~. Will cement cover a.ll possible productive horizons . . ,. .......... 5. Will surface casing cover all fresh water zones .. ........... · ~. Will surface csg. internal burst equal .5 psi/ft, to next string ?. Will all casing give adequate safety in collapse and tension ....... ~). Does BOPE have sufficient pressure rating ...... ' ......... dditional Requirements: Approval Recommended: .... -KLt/ JAL ,, HWK ~/<, L CS t HHtt JCM .I ~. ) Well History File APPENDIX Inforrnation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To inlprove the readability of the Well History file and to sirnplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special·effort has been made to chronologically organize this category of information. ) ) Memory Multi-Finger Caliper Log Results Summary .('/ k~9)\A \'l\ (c~\)b Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. September 22, 2005 8003 1 27/8" 6.5 lb. N-80 EUE Tubing Well: 212-24-1 (Long String) Field: Beluga State: Alaska API No.: 50-283-20037-00 \ ~;.~ \5 Top Log IntvI1.: Surface Bot. Log IntvI1.: 4,411 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the IIXN" Nipple @4,411' (Driller's Depth). I I I I I I I I I I I ["I, Ii I This log was run to assess the condition of the 2 7/8" tubing with respect to corrosive and mechanical damages. The 2 7/8" tubing logged appears to be in good to poor condition with respect to corrosive damage. A 42% wall penetration measuring 0.25" is recorded in the blast joint 108 (3,378'). Due to the apparent erosion opposing this penetration, there is a high probability that this is a hole in the blast joint. Also, a penetration measuring 0.14" is recorded in the blast joint 109 (3,385'). A wall penetration of 48% is recorded in joint 138 (4,185'). The damage recorded in the tubing appears mainly in the forms of isolated pitting, general corrosion, and lines of corrosion. No significant areas of cross-sectional wall loss are recorded throughout the tubing logged. Deposits are recorded in Joints 117 and 138, with a minimum 1.0. of 2.14" in joint 138 (4,208'). Cross..;sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. SCANNEIC!i li.H4N :1 íl 20D6 MAXIMUM RECORDED WAll PENETRATIONS: Probable Hole in Blast Joint (0.25") Isolated Pitting Isolated Pitting Corrosion Corrosion ( 42%) ( 48%) ( 42%) ( 42%) ( 40%) Jt. Jt. Jt. Jt. Jt. 108 @ 138 @ 127 @ 133 @ 115 @ 3,378 Ft. (MD) 4,185 Ft. (MD) 3,830 Ft. (MD) 4,047 Ft. (MD) 3,545 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 14%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Minimum 1.0. = 2.14" Minimum 1.0. = 2.18" Jt. Jt. 138 @ 117 @ 4,208 Ft. (MD) 3,596 Ft. (MD) No other significant 1.0. restrictions are recorded throughout the tubing logged. I Field Engineer: R. A. Richey Analyst: M. Tahtouh Witness: J. Braden I ProActive Diagnostic Services/ Ine. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memOi'l!og.com RECEIVE 0 Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 NOV 1 6 2.005 A\aska 0\\ &. Gas Cons. CommisS\Ot1 Anchorage I I I Well: Field: Company: Country: BRU 212-24-1 Beluga ConocoPhillips Alaska, Ine. USA I Nom.OD 2.875 ins 6.5 6.5 ppf Grade & Thread N-80 N-80 I I Penetration ami Metal loss (OJ,, wall) penetration body metal loss body 150 I 100 I 50 I 0 o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number ofjoints analysed (total 144) pene. 2 30 89 19 4 0 loss 17 124 3 0 0 0 I I Damage Configuration ( body) 60 I 40 I 20 I o isolated general line ring hole / poss pitting corrosion corrosion corrosion ibte hole I Number of joints damaged (total = 68) 57 9 1 0 I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.441 ins 2.5 ins Nom. Upset 2.875 ins 3.69 ins penetration body o 1 September 22, 2005 MFC 24 No. 040665 1.69 24 M. Tahtouh Upper len. 1.2 ins 1.2 ins Lower 1.2 ins Damage Profile (% wall) metal loss body 50 51 101 Bottom of Survey 144.1 Analysis Overview page 2 I I 100 I PDS EPORT JOINT TABULATION SH I Pipe: 2.875 in 6.5 ppf N-80 Well: BRU 212-24-1 Body Wall: 0.217 in Field: Beluga Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. I NominaII.D.: 2.441 in Country: USA Survey Date: September 22, 2005 I Joint Ji. Depth Pen. Min. Damage Profile No. (Ft.) Body 1.0. Comments (%wall) (Ins.) (ins.) 0 50 100 I 1 9 0.02 2.36 2 41 0.02 2.38 Lt. Deposits. 3 72 0.02 2.37 4 103 0.02 2.39 4.1 135 0 2.31 X Nipple I 5 136 0.03 2.37 6 168 0.03 2.39 7 199 0.03 2.40 8 230 0.02 2.39 I 9 262 0.ü3 2.41 10 292 0.02 2.38 11 324 0.03 2.38 12 355 0.04 2.38 Shallow pitting. Lt. Deposits. I 13 386 0.04 2.38 Shallow pittiIJZ,,_lJ,.º~posits. 14 417 0.03 2.33 15 449 0.03 2.39 16 480 0.04 2.37 Shallow pitting. I lL....._. 511 0.04 2.37 Shallow pitting. 18 543 0.03 2.37 Lt. Deposits. 19 575 0.03 2.38 Lt. Deposits. 20 606 0.04 2.38 Isolated pitting. Lt. Deposits. 21 637 0.04 2.34 Shallow pitting. Lt Deposits. I 22 668 0.02 2.40 Lt. Deposits. 23 700 0.02 2.41 24 730 0.02 2.37 Lt. Deposits. 761 0.04 2.36 Shallow pitting. I 794 0.04 2.40 isolated piting. 27 824 0.ü3 2.40 Shallow pitting. 28 856._ 0.04 ...V8 ShaIIQW.!Jjj;j:lllg. 29 888 0.03 2.38 Shallow pitting. I 30 919 0.ü2 2.38 Lt. Deposits. 31 950 0.03 2.40 32 982 0.02 2.41 33 1014 0.04 2.39 Shallow pitting. I 34 1045 0.02 2.38 35 1076 0.03 2.41 Lt. Deposits. 36 1108 0.02 2.41 37 1139 0.03 2.40 38 1169 0.03 2.41 I 39 1199 0.01 2.40 40 1230 0.02 2.38 41 1261 0.01 2.40 42 1293 0 0.02 2.39 I 43 1325 0.03 2.37 44 1357 0.03 2.40 45 1387 0.03 2.41 46 1419 0.03 2.40 Lt. Deposits. I 47 1449 0.02 2.37 48 1480 0.02 2.38 49 1511 0.02 2.37 I Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf N-80 Well: BRU 212-24-1 Body Wall: 0.217 in Field: Beluga Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. I Nomina! I.D.: 2.441 in Country: USA Survey Date: September 22,2005 I Joint Jt. Depth Pen. Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (I ns. ) (Ins.) 0 50 100 50 1543 0.04 2.38 Shallow pitting. Lt. Deposits. I 51 1574 0.02 2.41 52 1606 0.03 2.38 L1. Deposits. 53 1638 0 0.03 2.38 Shallow pitting. 54 1669 0.04 2.41 Shallow pitting. I 55 1701 0.03 2.40 Shallow pitting. 56 1732 0.03 2.35 Shallow pitting. Lt. Deposits. 57 1763 0.04 2.40 Shallow pitting. 58 1794 0.04 2.36 Isolated pitting. I 59 1825 0.02 2.38 L1. Deposits. 60 1855 0.01 2.40 L1. Deposits. 61 1885 0.03 2.41 62 1917 0.02 2.40 I 63 1949 0.00 2.38 64 1980 0.03 2.39 Shallow pitting. 65 2012 0.05 2.41 Isolated pitting. 66 2044 0.03 2.39 I 67 2075 0.02 2.41 68 2107 0.03 2.40 69 2139 0.03 2.39 Lt. Deposits. 70 2169 0.04 2.36 Shallow pitting. 71 2200 0.03 2.40 L1. Deposits. I 72 2231 0.04 2.39 Shallow pitting. 73 2262 0.03 2.36 Shallow pitting. 74 2293 0.03 2.40 75 2324 0.03 2.37 I 76 2355 0.03 2.40 77 2386 0.05 2.38 _~Jsolated pitting. 78 2418 0.04 2.40 Shallow pitting. Lt. Deposits. 79 2449 0.03 2.41 Shallow pitting. I 80 2481 0.03 2.41 81 2513 0.02 2.35 Lt. Deposits. 82 2544 0.01 2.38 83 2575 0.03 2.40 Shallow pitting. I 84 2606 0.07 2.38 Isolated pitting. 85 2638 0.04 2.40 Shallow pitting. 86 2669 0.02 2.42 87 2701 0.03 2.39 Shallow pitting. 88 2733 0.02 2.36 I 89 2764 0.04 2.40 Isolated pitting. 90 2795 0.03 2.36 Lt. Deposits. 91 2826 0.02 2.40 92 2856 0.01 2.40 I 93 2888 0.03 2.40 94 2919 0.03 2.41 95 2950 0.03 2.39 Shallow pitting. 95.1 2982 0 2.31 Safety Joint I 96 2983 0.03 2.40 Shallow pitting. 96.1 3015 0 2.31 SLIDING SLEEVE 97 3018 0.03 2.36 L1. Deposits. I Body Metal Loss Body Page 2 I I I PDS EPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf N-80 Well: BRU 212-24-1 Body Wall: 0.217 in Field: Beluga Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Ine. I NominaII.D.: 2.441 in Country: USA Survey Date: September 22, 2005 ~- Jt. Depth Min. Damage Profile I Joint Pen. No. (Ft.) Body 1.0. Comments (%wall) (Ins.) (Ins.) 0 50 100 97.1 3049 () 0 3.00 PACKER I 98 3059 () 0.03 2.35 Shallow pitting. U. Deposits. 99 3090 0.03 2.40 Shallow pitting. It Deposits. 100 3121 0.04 2.40 Shallow pitting. It. Deposits. 101 3152 0.03 2.39 Shallow pitting. It. Deposits. I ___L02 3183 0.03 2.41 103 3215 0.03 2.40 104 3247 0.03 2.39 Shallow pitting. 105 3278 0.03 2.40 Shallow pitting. I 106 3310 0.02 2.42 107 3340 0.01 2.39 Blast loint. 108 3361 0.25 2.38 Probable Holel Blast loint. 109 3381 0.14 2.23 Isolated piting. It. Deposits. Blast Joint. I 110 3402 0.03 2.32 Shallow pitting. It. Deposits. Blast Joint. 111 3421 0.04 2.27 Shallow pitting. Lt. Deposits. Blast Joint. 3442 0.01 2.27 It. Deposits. Blast loint. 3462 0.04 2.32 Shallow corrosion. Lt Deposits. 114 3493 0.05 2.35 Isolated pitting. Lt. Deposits. I 115 3525 0.09 2.33 Corrosion. Lt. Deposits. 116 3556 () 0.04 2.34 Shallow pitting. 117 3588 0.07 2.18 Shallow pitting. Lt. Deposits. 118 3619 0.00 2.35 Blast Joint. I 119 3640 0.02 2.33 Lt. Deposits. Blast loint. 120 3659 0.00 2.30 Blast loint. 121 3679 0.02 2.39 Blast loint 122 3700 0.01 2.37 Blast loint. I _JJ3- 3719 0.03 2.22 Lt. Deposits. Blast Joint. ___124~ 3739 0.07 2.35 Line Shallow pitting. Blast ¡oint. 125 3759 0.05 2.35 Isolated pitting. Lt. Deposits. 126 3790 0.07 2.27 Isolated pitting. Deposits. I 127 3822 0.09 2.34 Isolated pitting. Lt. Deposits. 127.1 3853 0 2.50 Safety Joint 128 3855 0.05 2.37 Isolated pitting. 128.1 3886 0 2.31 SLIDING SLEEVE I 129 3890 0.08 2.31 Isolated pitting. Lt. Deposits. 129.1 3921 0 3.00 PACKER 130 3928 0.07 2.38 Corrosion. Lt. Deposits. 131 3959 0.04 2.36 Shallow pitting. Lt. Deposits. 132 3990 0.03 2.33 Lt. Deposits. I 133 4022 0.09 2.32 Corrosion. Lt Deposits. 134 4053 0.04 2.33 Shallow pitting. Lt. Deposits. 135 4084 0.07 2.32 Corrosion. Lt. Deposits. 136 4115 0.08 2.36 Isolated pitting. Lt. Deposits. I 137 4146 0.03 2.33 Shallow pitting. Lt. Deposits. 138 4177 0.10 2.14 Isolated pitting. Deposits. 139 4208 0.05 2.32 Isolated pitting. Lt. Deposits. 140 4240 0.08 2.29 Corrosion. Lt. Deposits. I 141 4271 0.02 2.36 Lt Deposits. 141.1 4302 0 2.50 Safety Joint 142 4305 0.06 2.29 Isolated pitting. Lt. Deposits. I Body Metal Loss Body Page 3 I I I I Pipe: Body Wall: Upset Wall: Nominal I.D.: I I PDS REPORT JOINT TABULATION SH 2.875 in 6.5 ppf N-80 0.217 in 0.217 in 2.441 in Joint Jt Depth Pen. No. (Ft.) Body (Ins.) 142.1 4336 0 143 4340 0.06 143.1 4371 0 144 4378 0.04 144.1 4409 0 I I I I I I I I I I I I I I I Well: Field: Company: Country: Survey Date: BRU 212-24-1 Beluga ConocoPhillips Alaska, Ine. USA September 22, 2005 Min. 1.0. Comments (Ins.) 2.31 SLIDING SLEEVE 2.35 Isolated pitting. Lt Deposits. 2.38 PACKER 2.38 Shallow pitting. 2.21 XN NIPPLE Page 4 Damage Profile (%wall) o 50 100 Body Metal Loss Body - - - - - Well: Field: Company: Country: Tubing: Cross Tool speed'" 52 Nominal 10 '" 2.500 Nominal 00 '" 3.690 Remaining wall area'" 96 % Tool deviation 2 0 - - - BRU 212-24-1 Beluga ConocoPhillips Alaska, Inc. USA 3.69 ins 6.5 ppf N-80 Joint 1 - - - - - - - - os ross Sectio s Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: September 22, 2005 MFC 24 No. 040665 1.69 24 M. Tahtouh 3377.833 Finger 10 Penetration'" 0.25 ins Probable Hole in Blast Joint 0.25 ins'" 42% Wall Penetration HIGH SIDE'" UP Cross Sections page 1 - - - - - .. - - - Well: Field: Company: Country: Tubing: - - - BRU 212·24-1 Beluga ConocoPhillips Alaska, Inc. USA 3.69 ins 65 ppf N-80 Tool speed'" 47 Nominal ID '" 2.500 Nominal OD '" 3.690 Remaining wall area'" 93 % Tool deviation'" 4 0 1 depth 33 - - - - - - - p S Rep rt Cross S ons Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: September 22, 2005 MFC 24 No. 040665 1.69 24 M. Tahtouh Finger 19 Penetration'" 0.138 ins Isolated Pitting in Blast Joint 0.14 ins'" 23% Wall Penetration HIGH SIDE"" UP Cross Sections page 2 - - - - - - - - - - - - - - - - - - - s s rt ons Well: Field: Company: Country: Tubing: BRU 212-24-1 Beluga ConocoPhillips Alaska, Inc. USA 2.875 ins 6.5 ppf N·80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: September 22, 2005 MFC 24 No. 040665 1.69 24 M. T ahtouh at depth 41 Joint 1 Tool speed'" 47 Nominal 10 '" 2.441 Nominal 00'" 2.875 Remaining wall area = 98 % Tool deviation'" 6 0 Finger 7 Penetration'" 0.104 ins Isolated Pitting 0.10 ins'" 48% Wall Penetration HIGH SIDE = UP Cross Sections page 3 - - .. .. .. .. .. .. Well: Field: Company: Country: Tubing: .. BRU 212-24-1 Beluga ConocoPhillips Alaska, Inc. USA 3.69 ins 6.5 ppf N-80 Tool speed'" 47 Nominal ID 2.500 Nominal OD '" 3.690 Remaining wall area'" 1 00 % Tool deviation'" 11 0 117 .. .. .. .. .. .. .. .. .. ross S o ns Survey Date: ToolType: Tool Size: No. of Fingers: Analyst: September 22, 2005 MFC 24 No. 040665 1.69 24 M. Tahtouh depth 3 5 7 Finger 22 Projection'" -0.291 ins Deposits Minimum I.D. '" 2.18 HIGH SIDE'" UP Cross Sections page 4 .. .. .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: Tubing: BRU 212-24-1 Beluga ConocoPhillips Alaska, Ine. USA 2.875 ins 6.5 ppf N-80 Cross for Joint 138 Tool speed = 47 Nominal 10 '" 2.441 Nominal 00 = 2.875 Remaining wall area'" 1 00 % Tool deviation = 9 0 .. .. .. .. .. .. .. .. PDS R ross S ons Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: September 22, 2005 MFC 24 No. 040665 1.69 24 M. Tahtouh 4207.7 43 ft Finger 5 Projection'" -0.27 ins Deposits Minimum I.D. '" 2.14 ins HIGH SIDE = UP Cross Sections page 5 .. .. .. I I I I I I I I I I I I I I I I I I I BRU 212..24 Producer + T13N, R10W, NE 1/4 ASP: 323,388 CASING & TUSING Description Str. LbL Top API# 50-283-20037-00 Annulus Fluid: Gas Max Hole Angle: <10 Ground Level: 77.3' RKB to SL: 98.' RKB to Tbg Hanger: 20.7' 73 78 10/84 RWO trìple+ to ~lim¡nªte camm. & H20 source. Fix poor primary cement. Test 6 zones & sqz 06/92 09/94 CTU: TUSING JEWELRY & FISH Spud Date 8/19/73 Last Completion 11/1/84 Schematic Rev. 5/12/04 Hole by TDT Length ID OD