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Home My WebLink About194-144Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240807 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 2-72 50029237810000 224016 6/27/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON RBT END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 7/20/2024 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/16/2024 HALLIBURTON MFC MPU E-19A 50029227460100 224010 6/22/2024 HALLIBURTON COILFLAG NS-10 50029229850000 200182 7/18/2024 HALLIBURTON MFC NS-10 50029229850000 200182 7/18/2024 HALLIBURTON TEMP NS-32 50029231790000 203158 7/16/2024 HALLIBURTON MFC NS-32 50029231790000 203158 7/15/2024 HALLIBURTON TEMP PBU H-13A 50029205590100 209044 7/23/2024 HALLIBURTON RBT PBU L-246 50029237650000 223078 7/23/2024 HALLIBURTON IPROF PBU R-26B 50029215470100 210025 7/5/2024 HALLIBURTON RBT PBU R-36 50029225220000 194144 6/21/2024 HALLIBURTON RBT PBU V-216 50029232160000 204130 7/11/2024 HALLIBURTON IPROF PBU V-217 50029233340000 206162 7/11/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39365 T39365 T39365 T39366 T39367 T39368 T39369 T39369 T39370 T39370 T39371 T39372 T39373 T39374 T39375 T39376 PBU R-36 50029225220000 194144 6/21/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.07 13:19:30 -08'00' Reviewed By: P.I. 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Hunt 7/20/2024 2024-0720_Suspend_PBU_R-36_photos_jh Page 2 of 3 2024-0720_Suspend_PBU_R-36_photos_jh Page 3 of 3 Tubing pressure IA and OA pressures 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU R-36 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 194-144 50-029-22522-00-00 10162 Conductor Surface Intermediate Production Liner 9249 80 3113 9797 9774 20" 10-3/4" 7-5/8" 8865 30 - 110 30- 3143 27 - 9824 30 - 110 30 - 3086 27 - 8915 None 470 2480 5120 9774 1490 5210 8180 None None None Structural None None N/A Torin Roschinger Operations Manager Andy Ogg andrew.ogg@hilcorp.com 907.659.5102 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028279 N/A N/A Suspended N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2024.07.26 12:56:15 -08'00' Aras Worthington (4643) By Grace Christianson at 2:02 pm, Jul 26, 2024 WCB 9-30-2024 RBDMS JSB 073124 DSR-7/31/24 ACTIVITY DATE SUMMARY 7/20/2024 T/I/O = 400/400/400. Temp = NA. AOGCC SU Well inspection. Witnessed by Hunt. No flowline. Well house clean, Rain water in cellar SSV = C. MV = LOTO. IA, OA = OTG. 09:50 Daily Report of Well Operations PBU R-36 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:194-144 6.50-029-22522-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10162 9774 8865 None None 9774 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 3113 10-3/4" 30 - 3143 30 - 3086 5210 2480 Intermediate 9797 7-5/8" 27 - 9824 27 - 8915 8180 5120 Production Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth)None Packers and SSSV (type, measured and true vertical depth) None Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Sternicki, Oliver R Oliver.Sternicki@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4301 Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9249 Sundry Number or N/A if C.O. Exempt: 320-230 Junk Packer Printed and Electronic Fracture Stimulation Data Renew Suspension Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028279 PBU R-36 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:30 am, Jun 19, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.18 16:50:56 -08'00' SFD 6/23/2020 RBDMS HEW 6/19/2020 MGR26JUN20 DSR-6/22/2020 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:194-144 6.API Number:50-029-22522-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028279 Property Designation (Lease Number):10. 8. NONE R-36 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Renew Suspension Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10162 Effective Depth MD: 11. June 30, 2020 Commission Representative: 15. Suspended 5 Contact Name: Mcmullen, John C Contact Email: John.McMullen@bp.com Authorized Name: Mcmullen, John C Authorized Title:Well Interventions Superintendent Special Projects Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9249 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool No Packer No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 30 - 3143 30 - 3086 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 110 Structural 8180 Proposal Summary 13. Well Class after proposed work: No Packer None None Production 9774 8865 9774 None 30 - 110 470 10-3/4" 7-5/8" Contact Phone:+1 9075644711 Date: 5120 80 149020"Conductor 2480 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3113 5210 Intermediate 9797 27 - 9824 27 - 8915 Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:19 pm, Jun 02, 2020 320-230 Mcmullen, John C Digitally signed by Mcmullen, John C Date: 2020.06.02 13:21:03 -08'00' X DLB 6/2/2020 DSR-6/2/2020MGR12JUN20 10-404 Per 20 AAC 25.110 Suspended wells: (e) Next inspection shall be conducted 24 months before September 30 of 2025. Yesn Required? Comm 6/15/2020 dts 6/15/2020 JLC 6/15/2020 RBDMS HEW 6/16/2020 BP Exploration (Alaska) Inc. John McMullen., BPXA Well Integrity and Interventions Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 May 26, 2020 Mr. Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well R-36 (PTD #194144) Application for Renewal of Existing Suspension (10-403) Dear Mr. Price, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well R-36 on 09/15/2019 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: x Wellbore diagram illustrating the current configuration of the well x Suspended Well Site Inspection form documenting the pressures and site condition Prudhoe Bay Unit well R-36 was suspended on 11/01/2000. It has future utility as a sidetrack candidate. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is mechanically sound and secured with the top of cement at 9774’ in the 7-5/8” casing. Based on these conditions and the inspection on 09/15/2019 Prudhoe Bay Unit well R-36 meets the provisions required in 20 AAC 25.110 (a)(1). BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). In summary, BPXA believes Prudhoe Bay well R-36 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 529-9129 or Ryan Holt/ Andrew Ogg at 659-5102. Sincerely, John McMullen BPXA Well Integrity and Interventions Manager Attachments Technical Justification 2019 Suspended Well Site Inspection form Wellbore Schematic Prudhoe Bay Well R-36 (PTD #194144) Technical Justification for Renewal of Suspended Status May 26, 2020 Well History and Status Prudhoe Bay well R-36 (PTD #194144) was suspended on 11/01/2000 due to the Ivishak formation being wet and the well not being completed. This well has 7-5/8” casing set at 9824', below the top of the Sag river interval at 9705'. A cement plug was set across the open hole with a 50' lap brought inside the 7-5/8" production liner. Depth of cement is from TD at 10162' MD to 9774' MD. The well has future utility as a sidetrack opportunity for a development well. The well is mechanically sound as indicated by a passing MIT-IA to 3000 psi and a passing MIT-OA on 12/10/2004. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay Unit well R-36 is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O = -/300/600 psi. Request BPXA requests approval for renewal of the existing suspension status for R-36. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. STATE OF ALASKA - - - - -- --- ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations. shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection Z 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work Development 171 Exploratory ❑ 5. Permit to Dnlf Number: 194-144 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 1 6. API Number: 50-029-22522-00-00 7, Property Designation (Lease Number): ADL028279 e. Well Name and Number: PBU R36 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Wel(Condition Summary: Total Depth: measured 10162 feet Plugs measured 9774 feet true vertical 9249 feet Junk measured None feet Effective Depth: measured 9774 feet Packer measured None feet true vertical 8865 feet Packer true vertical feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 3113 10-3/4" 30-3143 30-3083 5210 2480 Intermediate 9797 7-5/8" 27-9824 27-8915 8180 5120 Production Liner Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) None Packers and SSSV (type, measured and None true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14.Attachments (requiredp.r20MC25.070.25.0]1.&25.290) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development R1 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ I GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 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: WA Authorized Name: Lastufka, Joseph Contact Name: Montgomery, Travis J Authorized Title: IM Speci fist Contact Email: Travis.Montgomery(d)bp.com Authorized Signature: Date. 19 J+J%- 1 Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 .r �� K6-pj('6'Ig 'AIZDM5LL0' OCT 15 2019 Submit Original Only 3/27/2019 T/1/0=200/550/350 LTT Master valve... (Pass) FWP's 200/550/350 T/I/O = ASV/265/610. Temp = SI. Pre-inspection (compliance). No AL or flowline. Dryhole tree. Temporary scaffolding in place. Wellhouse is clean of debris, no sheen on the water. 9/10/2019 ASV, MV(LOTO) = C. IA, OA = OTG. 16:40 T/I/O = ASV/300/600. Temp = Sl. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Jeff Jones. Pictures taken. Temporary scaffolding installed. Water in cellar with no sheen. Drip pan in wellhouse needs to be removed. 9/15/2019 IASV, MV = LOTO = C. IA, OA = OTG. 10:00 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: R-36 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1941440 API Number: 50-029-22522-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11!1/2000 Surface Location: Section: 32 Twsp: 12N Range: 13E Nearest active pad or road: R access road Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: rao or location surtace: Ije Location cleanup needed: "o nl Pits condition: X lw Surrounding area condition: Ejex Water/fluids on pad: Discoloration, Sheens on pad, pits or Samples taken: None Photographs taken (# and description): Y. T Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: U &- _ 140 frit 3 t pPe Cellar description, conditic Rat Hole: Wellhouse or protective z Well identification sign: Tubing Pressure (or casino Annulus pressures: Wellhead Photos taken (# Work Required: None Operator Rep (name and It ttture): Josh Prowant AOGCC Inspector: JC wl Other Obs rvers: Inspection Date: 9/15(2019 AOGCC Notice Date: Time of arrival: Time of Departure: Site access method: Access road NO 9/13/2019 i R=36 WELL NAME R•36 OWNER Prudhoe Bay Unil OPERATOR Be ExPlorellon (Alaska) Inc API NUMBER 50-029-22522-00-00 SUR LOCATION SW 1 4. Sec 32, T12N. RI n :TRILLING PERMIT 194-144 F �i AIMMOKIEL- � IP 'or 28 R-,16AP,&1 R-1 _ 1 R:IBA _: P.-196 C F-.37A - R-17 h_1 - �_t13 - R-03:. R'48 R_9AAL1 =' R- T-41 -.— - _ . -L - P"ZZ�.Li . - - R-RB.APBi PR-331M C R 31A. P-31CA _ -R_Z - C- -F-3 i L P.-1?A. -R-4 R-32APB1 P23 - -' R-` ft-G1 R-03E R-32 -- _ P-33 _ R-2'L1 r,r-�`a - �: R-p3 .. ._. 21 F-32 4 R-21L1-01... ..,� I - 33 - P4' F-43 P.-286 -Di- C. °P.-2? R-40P'E1 __R--``-:a 4.r AD d5 ;R-3%A R-10A.. C -. . .-1❑- F 30A - -- - P-28 R-i4 .. -. I eft. t4 R-33YAL7 'i ' 3 R=Y 7EPBl R-'? �i R-3'9AT IPPR1 F ��a�. _ ' J47A _ Lk 12 - ._ Mf-21 -R-2 R-3'5A J-0S . ` R-94 � P,4i1 y Zg . 4 5R-07A r� J-03 ` i4i-3a�v M-24 P, 12A R.b38 �. R-12 iY... _, K-29 ..-' 1n.PEn _Gil NI-37 N-2aA. � _ R14EPE1 TREE = DRYHOLE TREE WELLHEAD = 133/8" 5M FMC ACTUATOR= OKB. ELEV = 7 50.3' BF. ELEV = 20.19' KOP= 2226' Max k = 35 5422 Datum MD = _ _ 975V Datum TVD = 8800'SS SUSPENDED 3-1/2" TBG, 9.2# L-80,.0087 bpf, D = 2.992" 120' COND, 91.54, H-40, ID = 19.124" 1 Minimum ID = 2.992" @ 3- 3-11210 PUP JOINT 1 10-3/4" CSG, 45.5#, NT -80 LHE, O = 9.953' 1 1 7-5/8" CSG, 29.7#, NT -95 HS, D= 6-875' 1 1 982,V PERFORATION SUMMARY RE= LOG: ANGLEAT TOP PERF: Note: Refer to Production DB for historical pert data i REV BY COMMENTS DATE REV BY I COMMENTS NTEiVAL OpnlSgz Q4TE 03/14/01 rTPFf CONVERTEDTOCANVAS 03/15/01 SIS -MD FINAL 6-3/4' HOLE 10162' SAFETY NOTES - 7-5/8" CSG SET ON EMEI; BJCI' R-36 SUPS. WELL WAS OOMPLETED W1FMC COL TBG HGR ASSY. 6" OOL TBG FALSE BOWL & 4" CIW BP7 BELOW TBG HGR IS A 3-1/2" x 3' L-80 PUP JONT. SEEDRILLING REPORT FOR MORE NFO. r 1 1 3'3-1/2"PUP JOINT DATE i REV BY COMMENTS DATE REV BY I COMMENTS 12/02/94 1 ORIGINAL COMPLETION 03/14/01 SISSLT CONVERTEDTOCANVAS 03/15/01 SIS -MD FINAL 09/28/01 RNRP CORRECTIONS 10/10/19 JNVJMD JADD OKB, BF, & COND NFO T02000' SEAWATER OFCEMENT PRUDHOE BAY UNIT WELL: R-36 PERMIT No: 94-1440 API No: 50-029-22522-00 (Alaska) LJ • ~~G~~~ 0~ Q~Q~S~{~ /,~..w.E..~o~~oa Gary Preble Data Management Engineer `~- BP Exploration (Alaska), Inc. P.O. Box 196612 ~~~ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-36 Sundry Number: 310-266 Dear Mr. Preble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Chair DATED this ~ day of September, 2010. Encl. • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 24, 2010 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well R-36 (PTD #1941440) Suspended Well Inspection Report (10-404) Application for Renewal of Existing Suspension Dear Mr. Seamount, ~~ r ~>`~ (10-403) BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well R-36 on 8/1/10. Enclosed is a Report of Sundry Well Operations (10-404) with attachments documenting the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). Recent well events from this well indicate that this well is mechanically sound. Specific attachments include: • Suspended Well Site Inspection form documenting the well pressures and site condition • Wellbore diagram illustrating the current configuration of the well • Pad map and aerial photo showing well location and other wells within one- quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Prudhoe Bay Unit well R-36 was suspended on 11/1/00. It is located on a pad with active wells and/or service wells. Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10- 403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay Unit well R-36 is mechanically sound and secure and will meet the requirements for renewal of suspended status. • If you require any additional information, please contact me at 564-5637, Torin Roschinger/Jerry Murphy at 659-5102 or Chris Stone 564-5518. Sincerely, R. Steven Rossberg BPXA, Wells Operations Manager Attachments: Report of Sundry Operations (Form 10-404) with attachments: Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Pictures of wellhead and location Application for Sundry Approval (Form 10-403) with attachment: Technical Justification Cc: Roschinger/Murphy Harry Engel Mike Bill Chris Stone Mohamed Sayed Gary Preble ~r STATE OF ALASKA ' - ALAS AND GAS CONSERVATION COMMISSI~ t s ~ APPLICATION FOR SUNDRY APPROVALS ~'! ~n nnr. ~~ ~Rn ~0 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: RENEW SUSPENSION 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 194-1440 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22522-00-00 _ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ Spacing Exception Required? Yes ^ No PBU R-36 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028279 - PRUDHOE BAY Field / PRUDHOE BAY Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10162 - 9248.79 - 9774 8865 9774' TOC NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE 110 SURFACE 110 1490 470 Surtace 3113 0-3/4" 45.5# NT80LH 30 3143 30 3083 5210 2480 Intermediate 9797 7-5/8" 29.7# NT95HS 27 9824 27 8915 8180 5120 Production Liner Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - NONE Packers and SSSV Tvoe: NONE Packers and SSSV MD and TVD (ftl: 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ • Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ WDSPL ^ Suspended - 0 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Gary Pr ble Title Data Management Engineer Signatu Phone Date 564-4944 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~" Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ h .. I ..P~ ,.w ` ' . , ` Other: /~a.GG ytG.r~ ~-.~~° roves ~..~ zc~ ,~}qc z O l~ ~1 ~,~'h~-~- 5 ~- r rd Cat) ~ 1/ /P /] Subsequent Form Required: No,~ ~ -~,.~5 ~~..e._, APPROVED BY J~~ J Approved by: COMMISSIONER THE COMMISSION ~ Date: `J / - i r~~~ ~~ SEP 0=~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~ Form 10-403 Revised 1/2010 Submit in Duplicate •^ } Prudhoe Bay Oil Pool well R-36 Technical Justification for Application for Renewal of Suspension Status August 24, 2010 Well Status Prudhoe Bay Waterflood well R-36 (PTD #1941440) was suspended on 11/1/2000 due to the Ivishak formation being wet and the well not being completed. This well has 7-5/8 casing set at 9824', below the top of the Sag river interval at 9705'. A cement plug was set across the open hole with a 50' lap brought inside the 7-5/8" production liner. Depth of cement is from TD at 10162' MD to 9774' MD. The well is mechanically sound as indicated by a passing MIT-IA to 3000 psi and a passing MIT-OA on 12/10/04. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay Unit well R-36 is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O = 0/200/525. Annulus pressures were bled to zero on 8/18/10 and are stable. Request BPXA requests approval for renewal of the existing suspension status for R-36. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ INSPECT Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ WELL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ^ ~ 194-1440 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-22522-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~, r ADLO-028279 PBU R-36 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 10162 feet Plugs (measured) 9774" TOC feet true vertical 9248.79 feet Junk (measured) None feet Effective Depth measured 9774 feet Packer (measured) true vertical 8865 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110. 1490 470 Surface 3113 10-3/4" 45.5# NT80LHE 30 - 3143 30 - 3083 5210 2480 Intermediate 9797 7-5/8" 29.7# NT95HS 27 - 9824 27 - 8915 8180 5120 Production y~ ~ ri;{,j.4 Liner , ': Liner ~-~ ., '' _,.. Perforation depth: Measured depth: NONE - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) NONE 0 = _ Packers and SSSV (type, measured and true vertical depth) NONE ~~~l.:~ ~ ~ ~U j: 12. Stimulation or cement squeeze summary: Intervals treated (measured): Ala s~ ~~ u~!'~+1~f11SS3t+'~t Sk2~~` ~~ yy ~¢'~4,~ iJ~t ~g e.? Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: `~ Copies of Logs and Surveys Run Exploratory^ ~ D velopment ^~ Service ^ Daily Report of Well Operations X 16. Well Status after we SUSPENDED Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date d~e~s/ /~ rvnn IV-YVY I\GVIJG4 ~iwvo ~~~~.^• ~~ ~~~~ R6DMS AUG 2 5 2010 ~~ ~-//o ,~ • • Suspendeci'UVefi Sipe Enspection ~ot'm Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Narne: PRUDHOE BAY UNIT R-3G Field/Pool: PRUDHOE BAY I Pl;UDHOE OII_ Permit !# (PTD): 1941440 API Number: 50029225220000 Operator: SP EXPLORATION (ALASKA} INC Date Suspended: Surface Location: Section: 32 Twsp: 12N Range: 13E Nearest active pad or road: Prudhoe Bay R-Pad Take to Location Digital camera l3r-ief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downl~ole condition Site clearance documentation Sample containers for filuids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface loca#ion, including discoloration, fluids or sheens visil~le on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Fair Pad or location surface: Dry Location cleanup needed: Clean trash from well cellar. Trash debris in pit _ Pits condition: Good /Some wood & trash debris in pit Surrounding area condition: Good Water/fluids on pad: No • Discoloration, Sheens on pad, pits or water: None ' Samples taken: No Access road condition: Good Photographs taken (# and description): 4; Front of wellhouse, wellhead, well cellar and reserve pit Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2}well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC valves and wellhead. One master valve all valves in good condition and fully function. Cellar description, condition, fluids: 6" water /rag /gravel _ Rat Hole: N/A Wellhouse or protective barriers: Wellhause ~5~ £ (~ ado 6~ s~M-~- s~G- ~•/•/~ Wei! identification sign: Yes Tubing Pressure (a' casing if no tubing}: 0 psi Annulus pressures: IA: 200 psi OA: 525 psi _~ Wellhead Photos taken {## and description}: 1; picture of wellhead /master valve Work Required: Operator Rep {name and signature): Jerry Murphy :: )~,-~~E ''1;',.,.~~.~,,~;:~,r..~ J7,r "~ r=rci~~ /~"7r:~y ~~,~::;_ AOGCC Inspector: Jeff Jones Other Observers: :~ Ryan Holt Inspection Date: 8/1/2010 AOGCC Notice Date: 7/27/2010 Time of arrival: 10:30 AM Time of Departure 11/1/2000 10:45 AM Site access rmethod: Truck TREE= DRY HOLETREE WELLHEAD = 135/8" 5M FMC ACTUATOR = _? KB. ELEV = 49.1' BF. ELEV = 20.1' KOP = 2226' Max Angle = 35 5422 Datum MD= 9758' Datum ND = 8800' SS i31/2" TBG, 9.2#, L-80, .0087 bpf, ID= 2.992" I--I $' Minimum ID = 2.992" @ 0' 3-1/2" PUP JOINT 10-3/4" CSG, 45.5#, NT-80 LFE, ID= 9.953" ~ 3143' R-36 13-1/2" PUPJOINT 2000' HDIESEL TO 2000' 9774' H SEAWATER 9774' TOPOFCBVIBVT 7-5/8" CSG, 29.7#, NT-95 HS, ID = 6.875" H 9824' PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SF7= INTERVAL OpNSgz DOTE 6-3/4" HOLE 10162' DOTE REV BY COMMENTS DATE REV BY COMMENTS 12/02/94 OPoGINAL COMPLETION 03/14/01 SlS-SLT CONVERTED TO CANVAS 03/15/01 SIS-MD FINAL 09/28/01 RN/TP CORRECTIONS PRUDHOE BAY UNIT WELL: R-36 PERMT No: 94-1440 API No: 50-029-22522-00 Sec. 32, T12N, R13E BP Exploration (Alaska) bs14495.dgn ~. .,. d' ~ ~* ~'~ .~ 1 A_. "'~ Iiriw^.~w ~- x ~. a 4 ` ~.: ~Y R-36 Cellar ~ ,IIJL ~ ~ ~Q~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 J u ly 10, 2009 ,~I~ska ~il ~ G~~ G~~Sa ~~~r~a~sior~ ~~ .~..,~~,~~;.;U~. ~~Z~v~ {~x~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Anehar~~~ ~ `~ ~ ~ ~`~ -~~ ~, Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) R-pad nate Revised 7/10/2009 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al R-02 50029203540000 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6/22/2009 R-i 1 A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5l18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15l2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 025 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 025 NA 1.7 5l11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 {VA 2 NA 22.i 5/11i2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 u BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 1 ~ ~ Q~ (,,~ - i r ~- 3~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, ~ ~~ ~.:. „_~ ~ _ ~ ~.~~ : JUL A ~ 20~~ ~~~~~~ ~~i ~ Ga~ Con~. ~ommis~i~~ Anchor~~ Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and voiumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincere(y, ,.. ~~~~~ ~U;.. ~ .~_ 2(J~~ ~~ Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date R-pad 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 1830350 0.25 NA 0.25 !UA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 025 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA 162 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 J ~"~. STATE OF ALASKA f- -' ALASKA ,_ AND GAS CONSERVATION COMN. SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 194-144 300-251 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-22522-00 ¢~- ~~., 4. Location of well at surface ~,'~ifai¢~,~ [ 9. Unit or Lease Name 782' NSL, 3629' WEL, SEC. 32, T12N, R13E, UMAt top of productive interval //:/':~__. !; ' !U,~:ir,.~ ~!~: Prudhoe Bay Unit ~. ,-~' ' ? ~. 10. Well Number N/A At total depth '~ - ~ ':." ~~! R-36 2341' NSL, 465' WEL, SEC. 32, T12N, R13E, UM ~~,~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 49.45' ADL 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., orAband. 115. Water depth, ifoffshore 116. No. of Completions 11/19/1994 I 11/29/1994 I 12/02/4-eDz~ //" /- z~'-f'~-'l N/A I I -:~"- .... 'f,~ I MSL Zero I 17. Total Depth (MD+TVD) ] 18. Plug Back Depth (MD+TVD) 119. Directional Surv&Y'¢20. Depth where SSSV set] 21. Thickness of Permafrost 10162 9249 FT] 9774 8865 FT] [] Yes [] No / N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run Dual Induction, Sonic, DEN, NEU, GR, Caliper, SP, FMT 23. CASING, LINER AND CEMENTING RECORD CASING SE-I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx./ 10-3/4" 45.5# NT80LHE 30' 3143' 13-1/2" 1020 sx CS III, 375 sx Class 'G' Top Job, 138 sx CS II 7-5/8" 29.7# NT95HS 27' 9824' 9-7/8" 568 sx Class 'G' OR G 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9774' Abandonment Plug, 30 Bbls Class 'G' 2000' ~j ~ Ft'eezb ~t~c't with 92 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ~', Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS'MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate --9. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Sag River 9705' 8797' Shublik 'A' 9745' 8837' Shublik 'B' 9794' 8885' Shublik 'C' 9806' 8897' Sadlerochit / Zone 4B 9831' 8922' Zone 3 9968' 9057' Zone 2C 10047' 9135' 31. List of Attachments: Summary of Daily Drilling Reports ~2. I hereby certify that the foregoingis true and correct to the best of my knowledge Signed TerrieHubble '~~~,'"' ~ Title TechnicalAssistant Date /)0'L_~0'OO R-36 194-144 300-251 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ~,, i..~ ~!-.. '~i.i¢ [- ~ .. Form 10-407 Rev. 07-01-80 Well: R-36 Accept: 11/18/94 Field: Prudhoe Bay Spud: 11/19/94 APl: 50-029-22522-00 Release: 12/02/94 Permit: 194-144 Drilling Unit: Nabors 18E 11/19194 Move rig in and set up on site. Take on fuel. Take on water in pits. Nipple up Hydril and diverter lines. Mix spud mud. Strap BHA and pick up motor. Held safety meeting as well as pre-spud. Diverter function test. Test witness waived by John Spalding with AOGCC. Finish picking up BHA. Change stab sleeve, orient tools. Tag up at 107'. Fill hole and check for leaks. Drilling surface hole from 110' to 310'. 11/20/94 Drilling from 107' to 1178'. Made 11 stand short trip to DC's. Hole in good shape. Drilling to 1955' 11/21/94 Drilling to 2193'. Check for flow. Made 11 stand short trip to 1135'. Hole in good shape. Drilling to 3152'. Circulate for short trip. Check for flow. Pulled 26XX to HWDP - SLM - No correction. RIH. No fill. Hole in good shape. Circulate and condition mud and hole to run 10-3/4" casing. Dropped survey. Checked for flow. Blow down Kelly. POOH to run 10-3/4" casing. Lay down BHA. Rig up casers. 11/22/94 Ran 77 joints 10-3/4" casing. Pick up hanger and landing joint. Land casing with shoe at 3143'. Rig up to circulate. Circulate and condition mud for cement job. Reciprocate casing. Rig up cementing heads. Test lines to 2500 psi. Pumped 75 Bbls fresh water ahead of 1000 sx lead, Cold Set 3, 375 sx Class 'G' tail. Displaced with 294 Bbls mud. Reciprocate casing and had full returns. Bumped plug to 2400 psi. No cement to surface. Floats held. Rig down cementing head. Ran 1" pipe to 110'. BJ performed top job, pumping 138 sx Cold Set 2. Circulate cement to surface. Backed out landing joint and nipple down diverter. Nipple up Uni-head and BOP's. Test casing head to 1000 psi for 10 minutes. Held. Set test plug and rig up to test BOP's. Test BOP's, no leaks. Performed closing unit pump test. Installed wear ring. Strap and pick up 9-7/8" BHA. Orient tools, surface check, start run in hole. Tagged FC at 3063'. Circulate and prepare to test casing. 11/23/94 Test 10-3/4" casing to 3000 psi for 30 minutes, held. Drill plugs and FC at 3063', cement, float shoe at 3142' and 10' new formation to 3162'. Circulate bottoms up and balance mud. Performed leak-off test. Held 550 psi for 5 minutes w/9.2 ppg mud, EMW - 12.6 ppg. Drill 9-7/8" hole from 3162' to 4187'. Check for flow. Made 10 stand short trip to shoe. Hole in good shape, no fill. Drilling 9-7/8" hole to 5205'. Check for flow. Short trip to 4145'. Partial swabbing. Tight at 5094' on trip in. Wash and ream from 5094' to 5205'. Drilling from 5205' to 5575'. 11/24/94 Drill to 5882'. Circulate sweep around. Circulate bottoms up. Check for flow. Blow down Kelly. Observe well. POOH for Bit #3. Change out motor and MWD. RIH, hole in good condition and no fluid loss. Drill to 6850'. 11/25/94 Drilling to 6894'. Make short trip to 5826', hole in good condition. Drill to 7901'. Short trip to 6883'. Observed well prior to short trip, no problems. Drilling to 8345'. 11/26/94 Drill to 8969'. Short trip to 7890', no problems. Drill to 9590', hole is in good condition. R-36, Drill and Suspend Page 2 11/27/94 Drill to 9829'. Circulate bottoms up. POH. Make up BHA and run in hole. Ream from 9788' to 9829', lost returns. Work pipe and establish returns, mix 50 Bbl LCM pill and spot pill. Observe well, no loss. Pull 10 stands, observe well, no loss. Pump dry job, POH 16 stands, observe well. 11/28/94 POOH, lay down drill pipe and BHA. Rig up to run casing. Run 7-5/8" casing to bottom. Work pipe and try to establish circulation, could not circulate. Could swab returns on the up stroke. Mix and pump 50 Bbls LCM pill. Test cement lines, pump 20 Bbls fresh water and 70 Bbls of spacer, lead cement and tail cement. Drop top plug, pump with rig pumps, pump max. Strokes did not bump plug, floats held. No returns while cementing. 11/29/94 Rig down and lay down BJ tools. Unbolt BOP's and raise up to cut casing. Set emergency slips. Make rough cut on 7-5/8" casing. Make final cut, install 10-3/4" x 7-5/8" packoff. Nipple up BOP's. Test packoff to 3800 psi. Continue to nipple up BOP's and change rams to 3-1/2". Change out 5" Kelly to 3- 1/2". Place test plug and test same. Strap and pick up BHA and 3-1/2" drillpipe. 11/30/94 Tag cement at 9689'. Break circulation and drill cement to float shoe at 9740'. Test 7-5/8" casing to 3500 psi. Drill float shoe, cement to shoe at 9824'. Circulate and condition mud. Drill float shoe and 10 feet of new hole. Circulate and condition mud and perform integrity test. Drill ahead with 6-3/4" bit. TD'd well at 10162'. Circulate for short trip. Short trip to 7-5/8" shoe. Pump High-Vis sweep around. Drop EMS survey. Pump dry job, POH for logs. Rig up Atlas Wireline for logging. RIH with DIFL-AC- 2DL-CN-GR-Temp. 12/01/94 Finished running GR / SP / Sonic / ZDL / CNL / Temp from 10139' to 9801'. Pulled CNL / GR to 9400'. Logs showed +/- 20' oil. Ran Atlas FMT/GR tools. Took formation pressures. Maximum pressure 3574 psi at 10060'. RIH with mule shoe sub on 3-1/2" drillpipe to 9460'. RIH, tagged bottom at 10162'. Circulate and condition mud and hole to spot cement plug. Batch mix cement. Test lines to 2800 psi. BJ spotted abandonment plug in 6-3/4" open hole from 10162' to 9824' and to 9500' MD inside 7-5/8" casing - 324' above shoe. 150 sx Class 'G' (30 Bbls). POOH w/10 stands 3-1/2" drillpipe and circulate bottoms up. Slug drillpipe. POOH. 12/O2/94 Pick up 6-3/4" bit, 7-5/8" casing scraper. RIH to 9250'. Circulate and wait on cement at 9250'. RIH, tagged top of cement at 9587'. Drill out and pressure test cement plug. Testing cement plug witness waived by Bobby Foster with AOGCC. Drilling good cement from 9587' to 9774', PBTD. Circulate bottoms up. Test 7-5/8" casing to 3500 psi for 30 minutes. Displaced well with 600 Bbls treated sea water. Test 7-5/8" casing to 3500 psi for 30 minutes. POOH, lay down 3-1/2" drillpipe to 2000'. Displace and freeze protect 7-5/8" casing to 2000' with 92 Bbls of Diesel. Finish POOH, lay down 3-1/2" drillipipe and BHA. Lay down Kelly. Change top pipe rams to 5" and pull wear ring. 12/03/94 Nipple down BOP's. Nipple up tubing head adaptor. Pull 6" BPV. Set 6" coil tubing hanger with TWC valve installed. RILDS. Test adaptor flange, tree adaptor, master valve, tree cap; all to 5000 psi for 15 minutes. Pulled TWC valve and installed BPV. Test casing and BPV to 3500 psi for 10 minutes. Finished cleaning and emptying pits and cellar. Release rig. Baker Hughes INTEQ R-36 Directional Surveys 9, 741.0' Comments R'ECEIVED MAR I 0 199fi Alaska Oil & Gas Cons. Commission Anchorap~, BP EXPLORATION (Alaska) Inc. Pad R 36 slot Prudhoe Bay North SLope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <0 - 9741> Our ref : svy4555 License : Date printed : 17-Feb-95 Date created : 17-Feb-95 Last revised : 1?-Feb-95 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on nTO 20 37.100,w148 54 54.3?6 Slot location is n?O 20 44.791,w148 54 6.234 Slot Grid coordinates are N 5977262.686, E 635298.935 Slot local coordinates are 782.19 N 1647.67 E Reference North is True North BP EXPLORATION (Alaska) Inc. Pad R,36 Prudhoe Bay, North Slope, Alaska Measured Depth Inc[in. Azimuth Degrees Degrees 0.00 0.00 0.00 99.00 0.30 54.90 200.00 0.10 158.00 292.00 0.20 197.70 383.00 0.50 220.90 475.00 0.90 207.20 561.00 0.60 212.40 659.00 0.50 224.70 752.00 0.80 250.10 844.00 0.80 354.80 936.00 1.90 26.50 1027.00 3.10 26.10 1118.00 2.70 28.20 1210.00 2.60 26.80 1303.00 3.30 15.90 SURVEY LISTING Page 1 Your ref : PMSS <0 - 9741> Last revised : 17-Feb-95 True Vert. R E C T A N G U L A R Dogleg Vert Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 0.00 0.00 N 0.00 E 0.00 0.00 99.00 0.15 N 0.21 E 0.30 0.26 200.00 0.22 N 0.46 E 0.33 0.51 292.00 0.01 S 0.44 E 0.15 0.40 383.00 0.46 S 0.13 E 0.36 -0.07 474.99 1.40 S 0.46 14 0.47 -1.01 560.98 2.39 S 1.01 14 0.36 -1.93 658.98 3.12 S 1.58 14 0.16 -2.76 751.97 3.63 S 2.48 14 0.44 -3.79 843.97 3.21 S 3.14 14 1.38 -4.21 935.94 1.21 S 2.52 14 1.40 -2.79 1026.85 2.35 N 0.76 14 1.32 0.31 1117.74 6.45 N 1.33 E 0.45 3.95 1209.64 10.22 N 3.30 E 0.13 7.33 1302.51 14.68 N 4.98 E 0.96 10.75 1396.00 3.40 16.30 1488.00 3.90 15.90 1581.00 3.70 14.20 1673.00 3.30 18.70 1764.00 3.30 19.40 1395.36 19.90 N 6.49 E 0.11 14.33 1487.17 25.53 N 8.11 E 0.54 18.19 1579.96 31.48 N 9.71 E 0.25 22.17 1671.79 36.86 N 11.29 E 0.53 25.89 1762.64 41.82 N 13.00 E 0.04 29.54 1857.00 4.00 28.90 1950.00 4.90 44.70 2041.00 6.20 52.50 2133.00 7.90 59.90 2226.00 9.50 67.20 1855.45 47.18 N 15.46 E 0.99 34.04 1948.18 52.84 N 19.82 E 1.63 40.40 2038.75 58.60 N 26.45 E 1.65 48.85 2130.05 64.80 N 35.86 E 2.09 60.00 2221.98 70.98 N 48.47 E 2.09 74.04 2319.00 11.00 67.60 2412.00 12.90 68.30 2505.00 15.00 67.60 2598.00 16.20 64.10 2690.00 18.20 63.70 2313.49 77.33 N 63.75 E 1.61 90.57 2404.47 84.55 N 81.60 E 2.05 109.80 2494.73 92.98 N 102.37 E 2.26 132.18 2584.30 103.23 N 125.17 E 1.64 157.18 2672.18 115.20 N 149.60 E 2.18 184.38 2781.00 21.60 63.70 2872.00 24.40 62.70 2964.00 26.50 63.00 3056.00 28.40 62.00 3092.00 28.60 59.90 2757.74 128.92 N 177.36 E 3.74 215.34 2841.49 144.97 N 209.09 E 3.11 250.88 2924.56 163.00 N 244.26 E 2.29 290.38 3006.20 182.60 N 281.87 E 2.12 332.75 3037.84 190.94 N 296.89 E 2.84 349.89 3200.00 28.20 60.60 3292.00 29.30 61.30 3385.00 29.60 60.60 3480.00 31.20 60.21 3572.00 33.70 62.30 3132.84 216.43 N 341.48 E 0.48 401.09 3213.50 237.91 N 380.17 E 1.25 445.24 3294.48 260.11 N 420.14 E 0.49 490.86 3376.42 283.86 N 461.94 E 1.70 538.78 3454.05 307.57 N 505.22 E 2.98 588.04 3665.00 33.40 61.60 3757.00 33.80 61.60 3850.00 33.30 61.60 3943.00 33.10 61.60 4036.00 33.00 62.30 3531.56 331.73 N 550.58 E 0.53 639.37 3608.18 355.95 N 595.37 E 0.43 690.20 3685.69 380.39 N 640.58 E 0.54 741.52 3763.51 404.62 N 685.38 E 0.22 792.36 3841.46 428.46 N 730.14 E 0.42 843.01 4127.00 32.80 62.70 4219.00 32.80 62.30 4312.00 33.00 62.00 4404.00 32.80 63.00 4498.00 32.80 63.40 3917.87 451.29 N 773.98 E 0.32 892.40 3995.20 474.30 N 818.19 E 0.24 942.19 4073.28 497.90 N 862.85 E 0.28 992.65 4150.53 520.98 N 907.17 E 0.63 1042.58 4229.54 543.93 N 952.62 E 0.23 1093.48 Att data is in feet unless otherwise stated Coordinates fro~ slot fl36 and TVD from RKB (50.30 Ft above mean sea level). Vertical section is from wellhead on azimuth 64.85 degrees. Declination is 0.00 degrees, Convergence is 1.02 degrees. CalcuLation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad R,36 Prudhoe Bay,North Slope, Alaska Measured Depth Inclin. Azimuth True Vert. Degrees Degrees Depth 4590.00 32.50 64.10 4307.01 4683.00 32.40 63.70 4385.48 4776.00 33.60 63.70 4463.48 4869.00 33.70 63.40 4540.90 4961.00 33.90 63.70 4617.35 SURVEY LISTING Page 2 Your ref : PMSS <0 - 9741> Last revised : 17-Feb-95 R E C T A N G U L A R Dogleg Vert C 0 0 R D ! N A T E S Deg/lOOFt Sect 565.89 N 997.14 E 0.52 1143.10 587.84 N 1041.95 E 0.25 1193.00 610.28 N 1087.36 E 1.29 1243.64 633.24 N 1133.50 E 0.21 1295.16 656.03 N 1179.32 E 0.28 1346.32 5053.00 34.20 63.70 4693.57 5145.00 34.30 64.40 4769.62 5236.00 34.40 64.80 4844.75 5329.00 34.70 65.10 4921.35 5422.00 34.80 64.80 4997.76 678.86 N 1225.50 E 0.33 1397.83 701.51 N 1272.06 E 0.44 1449.60 723.54 N 1318.44 E 0.27 1500.94 745.87 N 1366.22 E 0.37 1553.69 768.31 N 1414.24 E 0.21 1606.70 5518.00 34.80 65.10 5076.59 5608.00 34.60 64.40 5150.58 5700.00 34.60 64.40 5226.31 5792.00 34.70 64.40 5302.00 5885.00 34.40 64.80 5378.59 791.51 N 1463.88 E 0.18 1661.48 813.36 N 1510.22 E 0.50 1712.72 835.94 N 1557.33 E 0.00 1764.96 858.54 N 1604.50 E 0.11 1817.26 881.16 N 1652.15 E 0.40 1870.01 5978.00 34.50 64.80 5455.28 6069.00 34.20 63.00 5530.42 6163.00 33.90 63.70 5608.30 6256.00 33.90 64.80 5685.49 6349.00 33.80 65.10 5762.73 903.56 N 1699.75 E 0.11 1922.62 926.15 N 1745.86 E 1.16 1973.95 949.75 N 1792.90 E 0.52 2026.56 972.29 N 1839.61 E 0.66 2078.43 994.22 N 1886.54 E 0.21 2130.23 6442.00 33.50 64.10 5840.14 6536.00 33.60 64.80 5918.49 6629.00 33.50 64.40 5995.99 6724.00 33.40 64.40 6075.26 6819.00 33.10 64.80 6154.70 6914.00 33.00 64.40 6234.33 7008.00 33.10 64.80 6313.12 7103.00 32.90 64.80 6392.80 7198.00 32.80 63.70 6472.61 7293.00 32.70 65.10 6552.51 7387.00 32.50 64.40 6631.70 7480.00 32.30 65.10 6710.22 7574.00 32.30 64.10 6789.68 7669.00 32.30 64.80 6869.98 7763.00 31.00 63.40 6949.99 1016.32 N 1933.10 E 0.68 2181.76 1038.73 N 1979.96 E 0.42 2233.71 1060.78 N 2026.39 E 0.26 2285.11 1083.40 N 2073.62 E 0.10 2337.47 1105.74 N 2120.67 E 0.39 2389.56 1127.97 N 2167.47 E 0.25 2441.37 1149.96 N 2213.78 E 0.26 2492.63 1171.99 N 2260.60 E 0.21 2544.37 1194.37 N 2307.01 E 0.64 2595.90 1216.58 N 2353.36 E 0.80 2647.29 1238.18 N 2399.16 E 0.45 2697.93 1259.44 N 2444.23 E 0.46 2747.76 1280.98 N 2489.60 E 0.57 2797.99 1302.88 N 2535.40 E 0.39 2848.75 1324.41 N 2579.77 E 1.59 2898.07 7857.00 29.60 64.10 7031.15 1345.39 N 2622.30 7952.00 27.60 64.40 7114.56 1365.15 N 2663.26 8046.00 25.80 64.10 7198.53 1383.49 N 2701.30 8141.00 24.30 66.90 7284.59 1400.20 N 2737.88 8234.00 22.10 68.30 73?0.07 1414.17 N 2771.74 E 1.54 2945.48 E 2.11 2990.95 E 1.92 3033.18 E 2.01 3073.39 E 2.44 3109.98 8329.00 8424.00 8518.00 8612.00 8705.00 8800.00 8894.00 8988.00 9082.00 9177.00 21.00 69.70 7458.43 1426.69 N 2804.31 E 1.28 3144.78 19.40 69.00 7547.58 1438.25 N 2835.01 E 1.70 3177.48 17.80 68.00 ?636.67 1449.22 N 2862.91 E 1.74 3207.40 15.60 68.70 7726.70 1459.20 N 2888.01 E 2.35 3234.36 13.70 69.00 7816.67 1467.69 N 2909.94 E 2.04 3257.83 12.90 68.30 7909.12 1475.64 N 2930.30 E 0.86 3279.63 12.90 69.70 8000.75 1483.16 N 2949.89 E 0.33 3300.56 12.20 69.40 8092.50 1490.30 N 2969.03 E 0.75 3320.92 11.60 69.40 8184.48 1497.12 N 2987.17 E 0.64 3340.24 11.30 69.40 8277.59 1503.75 N 3004.82 E 0.32 3359.04 ALL data is in feet unless otherwise stated Coordinates from slot ~r56 and TVD from RKB (50.30 Ft above mean sea level). Vertical section is from wellhead on azimuth 64.85 degrees. Declination is 0.00 degrees, Convergence is 1.02 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Ataska) Inc. Pad R,36 Prudhoe Bay, North Stope, Ataska SURVEY LISTING Page 3 Your ref : PMSS <0 - 9741> Last revised : 17-Feb-95 Heasured [nc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 9270.00 10.90 69.00 8368.85 1510.11 N 3021.56 E 0.44 3376.89 9365.00 10.60 70.40 8462.18 1516.26 N 3038.18 E 0.42 3394.55 9459.00 10.20 70.40 8554.64 1521.95 N 3054.16 E 0.42 3411.44 9553.00 9.80 69.70 8647.21 1527.52 N 3069.51 E 0.44 3427.69 9645.00 9.40 71.50 8737.92 1532.62 N 3083.98 E 0.54 3442.96 9741.00 9.00 72.20 8832.69 1537.40 N 3098.56 E 0.43 3458.19 All data is in feet unless otherwise stated Coordinates from slot ~r56 and TVD from RKB (50.30 Ft above mean sea [eve[). Vertical section is from wellhead on azimuth 64.85 degrees. Declination is 0.00 degrees, Convergence is 1.02 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad R,36 Prudhoe Bay, North Slope, Alaska SURVEY LIST[NG Page 6 Your ref : PHSS <0 - 9741> Last revised : 17-Feb-95 All data is in feet unless otherwise stated Coordinates from slot fl56 and TVD from RKB (50.30 Ft above mean sea level). Bottom hole distance is 3459.00 on azimuth 63.61 degrees from wellhead. Vertical section is from wellhead on azimuth 64.85 degrees. Declination is 0.00 degrees, Convergence is 1.02 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes [NTEQ Baker Hughes INTEQ R-36 EMS Surveys 9,849.0' 10,146.0' Comments BP EXPLORATION (ALaska) inc. Pad R slot f36 Prudhoe Bay North SLope, ALaska SURVEY L [ ST ] N G by Baker Hughes !NTEQ Your ref : EMS <9849~-10146'> Our ref : svy4562 License : Date printed : 17-Feb-95 Date created : 17-Feb-95 Last revised : 17-Feb-95 FieLd is centred on ?08179.340,5930615.440,999.00000,N Structure is centred on nTO 20 37.100,w148 54 54.376 Slot location is nTO 20 44.791,w148 54 6.234 Slot Grid coordinates are N 5977262.686, E 635298.935 SLot Local coordinates are 782.19 N 1647.67 E Reference North is True North BP EXPLORATION (ALaska) Inc. Pad R,36 Prudhoe Bay, North SLope, ALaska SURVEY LISTING Page 3 Your ref : ERS <9849'-10146'> Last revised : 17-Feb-95 Measured IncLin. Azimuth True Vert. R E C T A N G U L A R Dogleg Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt 9270.00 10.90 69.00 8368.85 1510.11 N 3021.56 E 0.44 9365.00 10.60 70.40 8462.18 1516.26 N 3038.18 E 0.42 9459.00 10.20 70.40 8554.64 1521.95 N 3054.16 E 0.42 9553.00 9.80 69.70 8647.21 1527.52 N 3069.51 E 0.44 9645.00 9.40 71.50 8737.92 1532.62 N 3083.98 E 0.54 9741.00 9.00 72.20 8832.69 1537.40 N 3098.56 E 0.43 9849.00 8.90 71.10 8939.37 1542.69 N 3114.51 E 0.18 9880.00 8.80 72.00 8970.00 1544.20 N 3119.03 E 0.55 9941.00 8.90 68.90 9030.28 1547.34 N 3127.87 E 0.80 10032.00 8.40 68.80 9120.24 1552.28 N 3140.64 E 0.55 10124.00 8.70 65.80 9211.22 1557.56 N 3153.25 E 0.58 10146.00 8.70 65.70 9232.97 1558.93 N 3156.28 E 0.07 ALL data is in feet un[ess otherwise stated Coordinates from slot #36 and TVD from RKB (50.30 Ft above mean sea level). Declination is 0.00 degrees, Convergence is 1.02 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad R,36 Prudhoe Bay, North S[ope, Alaska SURVEY LISTING Page 4 Your ref : EMS <9849'-10146'> Last revised : 17-Feb-95 AIl data is in feet un[ess otherwise stated Coordinates from slot #36 and TVD from RKB (50.30 Ft above mean sea level). Bottom hole distance is 3520.28 on azimuth 63.71 degrees from wellhead. Declination is 0.00 degrees, Convergence is 1.02 degrees. Calculation uses the minJn~rn curvature method. Presented by Baker Hughes [NTEQ Subject: Re: R-36 Date: Mon, 02 Oct 2000 14:43:52 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Hubble, Terrie L" <HubbleTL~bp.com> Terrie, Thanks, This should be sufficient. Blair "Hubble, Terrie L" wrote: Hi Blair, Apparently I left out some crucial information on my attachment to the R-36 10-403, requesting permission to change it from an Ops Shutdown status to a Suspended status. We would like to request a waiver for the surface plug requirements on this well as it is exists on an active pad and we feel that it is in a safe condition. This would preserve the ability to sidetrack the well when an optimum candidate has been identified. Thank you. Terrie Hubble Alaska Drilling & Wells 564-4628, MB7-5, Cube 737A 10/2/00 2:44 PM To: Alaska Oil & Gas Conservation Commission Date: September 26, 2000 From: Subject: Terrie Hubble Technical Assistant Permit #194-144, Approval #398-174 At this time we are respectfully requesting that we be permitted to change the status of this well from Operations Shutdown to Suspended. A 10-403 was submitted and approved 12/05/94 for an Operation Shutdown due to less than expected oil column in the Sadlerochit formation, This was followed up in 1996 and again in 1998 with a 10-403 to request an extension of this Operation Shutdown, Casing has been run to the top of the Sadlerochit and the Sadlerochit has been abandoned with cement, The Pad Engineer (Bryan McLellan, 564-5516) has once again informed me that BP Exploration would like to retain this well as a future sidetrack candidate. We recognize that we have far exceeded what is normally acceptable in keeping this well in an Operations Shutdown status and feel that this well remains in a satisfactorily shut-in and safe condition. /tlh .~-,. STATE OF ALASKA ALASK, .L AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change from OpsShutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 782' NSL, 3629' WEL, SEC. 32, T12N, R13E, UM At top of productive interval N/A At effective depth 2320' NSL, 520' WEL, SEC. 32, T12N, R13E, UM At total depth 2341' NSL, 465' WEL, SEC. 32, T12N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE -- 49.45' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number R-36 9. Permit Number 194-144 / 398-174 10. APl Number 50- 029-22522-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10162 feet true vertical 9249 feet Effective depth: measured 9774 feet true vertical 8865 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 80' 20" 3113' 10-3/4" 9797' 7-5/8" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Plugs (measured) Cement Plug top at 9774' (02/95) Junk (measured) Cemented MD TVD 260 sx Arcticset (Approx.) 1020 sx CS III, 375 sx Class 'G' 568 sx Class 'G' 110' 110' 3143' 3083' 9824' 8915' 0RIGINAL 13. A~achments [] Description Summary of Proposal 14. Estimated date for commencing operation September 26, 2000 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: [] Detailed Operations Program [] BOP Sketch Date Approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Bryan McLellan, 564-5516 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the for. egoing is true and correct to the best of my knowledge Signed TerrieHubble~~~ ~'~,~__~ Title TechnicalAssistant Conditions of Approval: Notify Commission so representative may witness ~C~F{-~¢.¢_.'O~)~l[)~u"'(d~ Plug integrity __ BOP Test __ Location clearance 6Z.)'d~ ~' * Mechanical Integrity Test __ Subsequent form required 1 O- ORIGINAL SIGNED EJ¥ Approved by order of the Commission D TCtytc~r Sesmount Form 10-403 Rev. 06/15/88 Date Commissioner Date Submit In Triplicate STATE OF ALASKA ALASKA wlL AND GAS CONSERVATION COM~gilSSION APPLICATION FOR SUNDRY APPROVAL I1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Extend Cps Shut Down 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 4. Location of well at surface 782' NSL, 3629' WEL, SEC. 32, T12N, R13E, UM At top of productive interval N/A At effective depth N/A At total depth 2342' NSL, 471' WEL, SEC. 32, T12N, R13E, UM 6. Datum Elevation (DF or KB) KBE = 48.8' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number R-36 9. Permit Number 94-144 / 94-323 / 96-75 10. APl Number 50-029-22522 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 10162 feet 9249 feet feet feet Length Size Structural Conductor 80' 20" Surface 3113' 10-3/4" Intermediate 9797' 7-5/8" Production Liner Plugs (measured) Junk (measured) Cemented MD TVD 260 sx Arcticset (Approx.) 110' 110' 1020 sx CS III, 375 sx Class 'G' 3143' 3082' 568 sx Class 'G' 9824' 8865' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None ORIGifqAL 13. Attachments [~ Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation July 1, 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: 17. I hereby certif~~.~e ~...~~and correct to the best of my knowledge James Signed ~Srnith Terrie Hubble, 564-4628 Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date [Approval Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Original Signed By Approved by order of the Commission David W. Johnston ~,.o?'-",~,l.9%,,.,_u/~),. Commissioner Form 10-403 Rev. 06/15/88 Submit In Triplicate ~ALASKA~ eare. d rvices rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: July 1, 1998 Frorn: Subject: Terrie Hubble Technical Assistant Permit #94-144, Approval ~94-323 & 96-75 A 10-403 was submitted and approved 12/05/94 for an Operation Shutdown due to less than expected oil column in the Sadlerochit Formation. This was followed up in 1996 with a 10-403 to request an extension of this Operation Shutdown. Casing has been run to the top of the Sadlerochit and the Sadlerochit has been abandoned with cement. The plan was to compete and perforate with a coiled tubing unit within three to six months to exploit the Sag River Formation. The Pad Engineer, Thomas McCarty, informed me that up until a few months ago R-36 was slated to be a sidetrack candidate. However, it has been found that the potential target would be cheaper and easier to reach from a new surface location. At this time R-36 remains shut in and alternatives are still being evaluated. We would like to request that the status of Operation Shutdown be continued for two more years. /tlh C' DRY HOLE TREE ~.~.. R 36 ..... ~qELLHEAD: 13 5/8" - 5M FMC " KB ELEV = ACTUATOR: -- ~ ~ ~ -- GL ELEV = z .... ' 3-1/2" PUP DIESEL JOINT OA CEMENTED 2/10/95 TO ~ 3oo' LEFT IN CSG 10-3/4", I 3143,I ~~ ~ 45.5#/ft, NT-80LHE Butt NOTES: 1.7-5/8" CASING SET ON EMERGENCY SLIPS. m 2. WELL WAS COMPLETED W/FMC COIL TUBING HANGER ASSEMBLY. (6" COIL TUBING FALSE BOWL AND 4" CIW BPV. BELOW THE TUBING HANGER IS A 3-1/2" x 3' L-80 PUP JOINT. 3. SEE DRILLING REPORTS FOR MORE INFO. I'rl 7-5/8", 29.7# 9824' I ,~ ii:'~i:?~iii!iiiil,i:.i?ii!iiii!i:i~:~i k NT95HS NSCCJ PERFORATION SUMMARY:'::-~":~::, ':".... ?;?:::::' ' ': "::':. !SIZE SPF INTERVAL OPEN/SQZ'D ......................... 6-3/4" HOLE TD AT 10162' DATE REV. BY COMMENTS PRUDHOE BAY UNIT 12-2-94 U. LINDER WELL DRILLED BY NABORS 18-E WELL:R'36 (43-32-12-13) 2/11/95 Chittenden OA CEMENTED APl NO: 50-029-22522 o7/ol/98 T. Hubble CONTINUED OPS SHUTDOWN STATUS BP/ARCO PBU DRILLING STATE OF ALASKA ALA~::~-q-IL AND GAS CONSERVATION COMMISSI~'''-' ' REPORT L. SUNDRY WELL OPE,,ATIONS ,Jperations performed: Operation shutdown'~ Stimulate__ Plugging.__ Perforate__ Pull tubing__ Alter casing __ Repair well__ Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 782' NSL, 3629' WEL, SEC. 32, T12N, R13E At top of productive interval At effective depth At total depth 2342' NSL, 471' WEL, SEC. 32, T12N, R13E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 7. Unit or Property name Prudhoe Bay Unit 8. Well number R-36(43-32-12-13) 9. Permit number/approval number 94-144 / 96-75 10. APl number 50.029-22522 11. Field/Pool Prudhoe Oil Pool feet 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length .. measured true vertica§ubsea 10162 9249 Size feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth BKB Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations ,,,/~,~ OilX Gas Suspended 17. I herebycertify,tJci~'t the ~egoin.q,,~ t,r, de and,correct-to the best of my knowledge. Signed~'~'~ '-~ ~-~-~J~ ~ r~_~~_~ TitleTechnicalAssistant/ll Form 10-404 Rt~v 06/15/88 Service Date/,~<'~,-~ SUBMIT IN DUPLICATE 02/08/95 R-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Down squeeze outter annulus procedure performed using the following fluids: SUMMARY BEGIN EFFLUENT WATER FLUSH SWITCH TO CEMENT SWITCH TO DRY CRUDE SWITCH TO DIESEL SD PUMPING Fluids Pumped BBLS. Description 300 Effluent water 113 Dead Crude 15 Diesel 428 TOTAL 02/10/95 NRWO OPERATIONS Outter annulus down squeeze #2 procedure performed using the following fluids: SUMMARY START DOWN OA W/EFFLUENT WATER. SD WATER SUPPLY PROBLEM RESTART PUMPING SWITCH TO CEMENT. ON CEMENT SWITCH TO DRY CRUDE. ON DRY CRUDE SD PUMPING. OA PRESSURE TEST TO 1000 PSI, LOST 150 PSI IN 30 MIN. FAILED PRESSURE TEST. Fluids Pumped BBLS. Description 300 Effluent Water 57 Cement 113 Dry Crude 470 TOTAL NRWO OPERATIONS 02/11/95 Pressure test outter annulus procedure performed using the following fluids: SUMMARY START PUMPING DOWN OA W/METHANOL. SHUT DOWN AND MONITOR LOST 150 PSIG AFTER 30 MIN. TEST BLEED DOWN OA RIG DOWN HB&R. WELL LOST 150 PSIG AFTER 30 MINUTE TEST. Fluids Pumped BBLS. Description 2 Methanol 2 TOTAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown x Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance__ Perforate __ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration Development x KBE = 48.8' feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service __ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 782' NSL, 3629' WEL, SEC. 32, T12N, R13E At top of productive interval At effective depth At total depth 2342' NSL, 471' WEL, SEC. 32, T12N, R13E ORIGINAL R-36 (43-32-12-13) 9. Permit number 94-144 / 94-323 10. APl number 50- 029-22522 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3113' Intermediate 9797' Production Liner Perforation depth: measured None 1O162 9249 Size 20" 10-3/4" 7-5/8" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth 260 sx Arcticset (Approx.) 1020 sx CS 111/375 sx 'G' 568 sx Class 'G' 110' 3143' 9824' True vertical depth 110' 3082' 8865' R, ECE \/ED Alaska 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation Extending Current Status 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended__ Service 17. I hereby certify that the~foregoing is true and correct to the best of my knowledge. Signed ¢~.,f ~ ~ Title SeniorDrillingEngineer ' ~. ,] FOR COMMISSION USE ONLY Conditions of approval: No'tify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance __ Mechanical Integrity Test Subsequent. form required i0- Z/CO '7 -- Ongma~ Signed By 0avid W. Johnston Approved by order of the Commission I Approval No. Approved Copy ~,~/~d Date Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE _~.,~ ~hea r'ed n/ices rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: March 29, 1996 From: Subject: Terrie Hubble Technical Assistant Permit #94-144, Approval #94-323 A 10-403 was submitted and approved 12/05/94 for an Operation Shutdown due to less than expected oil column in the Sadlerochit Formation. Casing has been run to the top of the Sadlerochit and the Sadlerochit has been abandoned with cement. The plan was to compete and perforate with a coiled tubing unit within three to six months to exploit the Sag River Formation. There are no immediate plans to complete this well, but it will be evaluated for possible future completion. At this time we would like to request that the status of Operation Shutdown be continued for another year. /tlh LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 6 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, ~~/~~ described below Enclosed, please find the data as ° WELL # DESCRIPTION ECC No. R-36 (43-32-12-13) 1 LDWG TAPE & LIST Run # 1 6311.00 Please sign a ~ Suite 201 ~ Anchorage, AK 99518 - /,,' Attn. Rodney D. Paulson ~ ory~ ~o (~0v) ss~-vs0~ Received by:~~~~~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 5 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, ~I Enclosed, please find the data as described below: ~ / ~O f' WELL # DESCRIPTION -~ R-36 (43-32-12-13) 1 DIFL/GR FINAL BL+RF Run # 1 1 ZDL/CN FINAL BL+RF Run # 1 1 BHOLE PROF FNL BL+RF Run # 1 1 SSTVD FINAL BL+RF Run # 1 R-36 (43-32-12-13) 1 FMT/GR FINAL BL + RF Run # 1 ECC No. 6311.00 6311.01 Please sign and retur~as Wireline~~~ / SU' ~ Attn. Rodney D. Paulson '/ / Or FA~/to 1907) 563-780' ' ' 3 - --~ STATE OF ALASKA A,- ._ .,A OIL AND GAS CONSERVATION COMMIS,.,..N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend __ Operation Shutdown X Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance__ Perforate __ Other __ At effective depth At total depth 2342' NSL, 471' WEL, SEC. 32, T12N, R13E 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration Development x KBE = 48.8' feet Exploratory 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Ser~ce__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 782'NSL, 3629' WEL, SEC. 32, T12N, R13E R-36 (43-32-12-13) At top of productive interval 9. Permit number 94-144 10. APl number 50- O29-22522 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor 80' Surface 3113' Intermediate 9797' Production Liner Perforation depth: measured None 10162 feet Plugs (measured) true vertical 9249 feet measured feet Junk (measured) true vertical feet Length Size Cemented 20" 260 sx Arcticset (Approx.) 10-3/4" 1O20 sx CS III/375 sx "G" 7-5/8" 568 sx Class "G" ORIGINAL true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Measured depth True vertical depth 110' 3143' 9824' 110' 3O82' 8865' RECEIVED DEC - 2 1994- ~jtt & Gas Cons. Commission Anchorc, ',~ 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 12/1/94 16. If proposal was verbally approved Name of approver B. Wondzell 11/30/94 Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that thee foregoing is Signed Conditions of approval: l~tify Commission so representative may witness Plug integrity ~ BOP Test Location clearance~ Mechanical Integrity Test Subsequent form required 10- ~.o '"'/ Original Signed By ~- David W. Johnston Approved by order of the Commission ,.i . true and correct to the best of my knowledge. Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY I Approval No. .Approved Cb p,.y . R~U~ed , Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 10. 11. PROPOSED OPERATION SHUTDOWN PROCEDURE WELL R-36 [ 43-32-12-13 ] PBU Well R-36 will have its operations shut down due to less than expected oil column in the Sadlerochit Formation. The well is slated to be completed and perforated with 3-1/2" coiled tubing within 3 to 6 months to exploit the Sag River Formation. The following is a proposed plugging program to secure the well during the shutdown period to meet the requirements of A©GCC regulations 20 AAC 25.072. Blair Wondzell with the AOGCC has given verbal approval to the following shutdown operation for R-36 on 11/30/94. 1. Contact AOGCC representative to discuss and witness the program for the operation shutdown of well R-36. 2. RIH with 3-1/2" open-ended drillpipe to TD. Break circulation and condition mud before going into open hole. 3. Circulate and condition mud at TD (10162' MD). 4. Lay 26 bbls of balanced cement plug from TD (10162' MD) to 150' MD above the 7-5/8" casing shoe (9824' MD). Pump 30 bbls water ahead of cement plug and appropriate amount of water spacer behind to balance the cement plug (+/- 6 bbls water). 5. POOH. P/U 6-3/4" bit. RIH to top of cement. Wait on cement for a minimum 12 hours. Drill out and dress off cement to at least 9774' MD (50' above 7-5/8" casing shoe). Notify AOGCC so representative will be present to witness tag and drill out/dress off of cement plug. 6. Test cement plug and casing to 3500 psi for 30 minutes. Displace well to inhibited seawater. Retest casing to 3500 psi for 15 minutes. 7. POOH and lay down drillpipe to 2000' MD. Circulate and displace top 2000' with 100 bbls diesel for freeze protection. Observe well for flow. 8. Continue POOH and lay down drillpipe. 9. Run 1 joint 4-1/2" tubing below 4" tubing hanger and land same with TWC valve. N/D BOPE and N/U dry hole tree. Test tree to 5000 psi. Pull TWC valve. Set BPV. Test BPV to 3500 psi by side outlet port on casinghead. Complete end of well reports and handover forms. 12. Release rig and move rig. Drlg Engr Drlg Supvt,~ DEC -'2 1994 /ZT// / %'~,csg~. Oil & Gas Cons. Commissio, Anchors. ,' Well Plan Summary 5-1/2" PLUG AND ABANDONMENT BALANCED CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140° F BHST: 220° F at 8800' TVDSS. PREFLUSH: 30 bbls fresh water CEMENT TYPE' CLASS G WEIGHT: 15.8 ppg APPROX. # SACKS- 130 ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0.03% A-2 + 1 gal FP-6L YIELD' 1.15 ft3/sx MIX WATER' 4.96 gps THICKENING TIME: 45 min. @ Surf + 3 hrs @ 140°F FLUID LOSS: less than 100 cc/30 minutes @ 140°F FREE WATER: 0 cc NOTE: Ensure fluid loss and compressive strength test are run on cement and reported prior to pumping cement slurry. CEMENT VOLUME: 1. Open hole (6-3/4") + 30% excess 4. 150' of cement inside the 7-5/8" casing. RECEIVED DEC -'2 1994 Oil & Gas Cons. Commission Anchorr.. ~ Well Plan Summary MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' David Johnston, Chair~ Blair Wondzell, ~ P. I. Supervisor [z(, FROM' Bobby Foste SUBJECT: Petroleum Inspector DATE: FILE NO: November 29, 1994 QINIK3BD.doc Rig Inspection - Nabors 18E BPX- PBU - R - 36 Prudhoe Bay Field Tuesday, November 29, 1994: I traveled this date to BPX's well R-36 being drilled by Nabors rig 18E and did a walk through inspection. The rig was clean and orderly and ali equipment seemed to be in good working order. All of the BOPE equipment and related items, as the attached Rig / BPS Inspection Report shows, were in compliance. Summary: i did a Rig / BPS Inspection on Nabors rig 18E and found all items to be in good shape and in compliance. Attachment: QINIK3BD.XLS ~'~ STATE OF ALASKA ~--, ALASKA O,,. AND GAS CONSERVATION ~,~MMISSION RIG i BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling X Workover Cmpl. UlC DATE: Well Name: R-36 NABORS Rig No. 18E Rep. BPX Rep. DON DUBOIS Section 33 T. 12N R. 13E M. U 11/29/94 PTD# 94-144 DON DUBOIS Rig Ph.# 659-4608 (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press Annular preventer Pipe rams Blind rams Stack anchored Chke/kill line size Ail turns targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) REMARKS: :. ITEMS MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Trip tank (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor.valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors (H2S & methane) Hydraulic choke panelI Choke manifold ITEMS:: · (E.) MISC. EQUIPMENT Flare/vent line All turns targeted choke lines) Reserve pit tankage Personnel protective equip, avail. Ail Drillsite Supervisors Trained For Procedures iH2S probes Rig housekeeping IN IN:COMPLIANCE IN COMPLIANCE RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Propedy Entered On Daily Record? YES 11/28/94 NONE Kill Sheet Current? Distribution: ofig - Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector AOGCC REP: OPERATOR REP: FI-022 (Rev. 3/93) BOBBY D. FOSTER DON DUBOIS QINIK3BD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION November 18, 1994 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 [/I/ALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re .' Prudhoe Bay Unit R-36 BP Exploration (Alaska), Inc. Permit No~ 94-144 Sur. Loc. 782'NSL, 3629'WEL, Sec. 32, T12N, R13E, UM Btmhole Loc. 2342'NSL, 433'WEL, Sec. 32, T12N, R13E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill dOes not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Doug Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ pHw,h:d on ~'ecycle,J ppp,u h y (~;. 1 t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill CIIlb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 49.1' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6~12 ADL 282 7~ ;4. Location of well at surface 7. Unit or property Name 11. Type Bond(~e 20 AAc 25.025) 782' NSL, 3629' WEL, SEC. 32, T12N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2317' NSL, 485' WEL, SEC. 32, T12N, R13E R-36 (43-32-12-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 2342' NSL, 433' WEL, SEC. 32, T12N, R 13E 11/20/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(aOandTVD) property line ADL 28278-433 feet R-9-30' @1973'MD feet~ 2560 10140' MD/9247' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~9oo feet Maximum hole an~]leao. 59 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5// H-40 Weld 80' 30' 30' 110' 110' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NT8OLHE Butt 3094' 29' 29' 3123' 3066' 1000 sx CS IIi/375 sx "G"/250 sx CS II 9-7/8" 7-5/8" 29. 7# NT95HS NSCC 9453' 28' 28' 9481' 8601' 9-7/8" 7-5/8" 29. 7# 13CR80 NSCC 659' 9481' 8601' 10140' 9247' 745 sx Class "G" Conting -ency 6-3/4" 5-1/2" 17# 13CR80 NSCC 609' 9331' 8456' 10140' 9247' 110 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface RECEIVED Intermediate Production Liner ~OV -'9 1994 Perforation depth: measured Alaska 0il & Gas Cons, Commission true vertical ~n~h0rag~, 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilli~ng program ITl Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the !0~go~.ng is true and correct to the best of my knowledge Signed ?fJ~/~~¢~ Tit le Drilling Engineer Supervisor Date/)-'~'-'~ - / Commission Use Only Permit Number IAPI number IApproval date See cover letter ~/-/Z'-//d/Z~,,' 150. o.~.<~- .~_ ~'2.~.~_._I for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required [] Yes ~1 No Hydrogen sulfide measures [] Yes J33~ No Directional survey required ~ Yes [] No Required working pressure for BOPE CI2M; I-'I3M; 1~[5M; []1OM; I-I15M; Other: by order of Approved by ORIGINAL SIGNED BY Commissioner ~ne commission Date//--/ Form 10-401 Rev. 12-1~ GLASS Submit in triplicate Well Plan Summary I WellName: l R-36PBU [ Type of Well (producer or injector): [ Producer ISurface Location: Target Location: Bottom Hole Location: 781' FSL 3629' FEL Sec 32 T12N R13E UM 2317' FSL 485' FEL Sec 32 T12N R13E UM 2342' FSL 433' FEL Sec 32 T12N R13E UM I AFE Number: I 4P0617 [ I Estimated Start Date: I Nov 20, 1994 I MD: [ 10140' I I TVD: I Well Design (conventional, slimhole, etc.): I Rig: [Nabors 18-E I Operating days to complete: [ 15 19247' I IRT-GL 126-2' IK E:1 49.1' I Slimhole producer I I Formation Markers: Formation Tops MD TVD (BKB) Base Permafrost 1969' 1969' Ugnu Zone 4A 4556' 4299' Top Seabee (CM3) 6496' 5969' Kuparuk/Put River Absent Absent IKRU/LCU 8173' 7413' Top Sag River 9681' 8795' Top Shublik 9681' 8795' Top Sadlerochit 9808' 8919' ~, l~ ~ [: !V [2 ~ Target 9808' 8919' Total Depth 10140' 9247' NO'v' - "' ~""' Alaska Oil & (las Con~. P, nmmleeln Casing/Tubin Program: Wt/Ft Hole Siz{[ Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80' 30'/30' 1107110' 13-1/2" 10-3/4" 45.5# NT80LHE Butt 3094' 29'/29' 3123'/3066' 9-7/8" 7-5/8" 29.7# NT95HS N$CC 9453' 28'/28' 9481'/8601' 9-7/8" 7-5/8" 29.7# 13Cr-80 NSCC 659' 9481'/8601' 10140'/9247' Contingency 6-3/4" 5 1/2" 17# 13Cr-80 NSCC 609' 9331'/8456' 10140'/9247' Tubing 4 1/2" 12.6 13Cr-80 NSCT 9554' 27'/27' 9581'/8698' Well Plan Summary Logging Pro Open Hole Logs: 13 1/2" Hole 9 7/8" Hole 6 3/4" Hole Cased Hole Logs: 7 5/8" Casing 5 1/2" Liner 'ram: None GR/DIFL/BHCA/CNL/SP and RFT (if well is longstringed) GR/DIFL/BHCA/CNL/SP and RFT (if well is not longstringed) None Optional SBT and Gyro Mud Program: I Special design considerations l None Surface Mud Properties: [SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 9 15 tO tO tO tO tO tO tO 9.5 300 60 60 80 10 25 Intermediate Mud Properties: I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 5 to to to to to to to 10.0 50 15 10 20 10 10 Production Mud Properties: I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8 30 8 3 7 8 6 tO tO tO tO tO tO tO 9.2 45 13 10 15 9 8 NOTE: Keep annular velocities around drill pipe at or above 220 ft/min wherever possible Directional: I KOP: I 1900' Maximum Hole Angle: Close Approach Well: 30.59 degrees away) R-9 at 1973' (30' away) and R-10 at 2455' (32' The above listed wells will be secured during the close approach. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. R E £ £ Diverter, BOPE and drilling fluid system schematics on file with AOGCC. I¥ ~!0V '- 9 1994 Well Plan Summary ~x!~.~C,a 0ii & Gas Cons. Commission gnchora;? PROPOSED DRILLING AND COMPLETION PROGRAM WELL R-36 | 43-32-12-13 1 PBU 1. MIRU. NU diverter and function test same. 2. Drill 13-1/2" hole. Run and cement 10-3/4", 45.5#, NT-80 Buttress casing to surface. o Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Function test BOPE to 5000/250 psi. . Test 10-3/4" casing to 3000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 10-3/4" shoe. o Longstring Option: Directionally drill 9-7/8" hole to TD. Run a 7-5/8", 29.7#, NT-95 NSCC by 7-5/8", 29.7#, 13Cr-80 NSCC casing string and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dry crude. Bump the plug with filtered seawater. Test casing to 3500 psi. 6a. Non-longstring Option: Directionally drill 9-7/8" hole to the 7-5/8" casing point above the top of Sag River. Run a 7-5/8", 29.7#, NT-95 NSCC casing string to within 10' of 9- 7/8" TD and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dry crude. 6b. Drill out of 7-5/8" casing with a mud weight of at least 0.5 ppg over the highest anticipated mud weight to used while drilling 6-3/4" hole for formation integrity test. Directionally drill the 6-3/4" hole to TD. Run 5-1/2", 17#, 13 Cr-80 NSCC liner from TD to 150' inside 7-5/8" casing shoe and cement using Class G cement. 6C. Clean out to 5-1/2" float equipment. Change over to filtered seawater completion fluid. Test casing and lap to 3500 psi. . Run 7-5/8" production packer on the 4-1/2", 12.6~, 13 Cr-80 NSCT tubing. A subsurface safety valve with dual control lines will be placed 10ft below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with diesel from surface to 2100' TVDBKB. Set and test packer. 8. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be injected down CC-2A. Tubing Size: 4-1/2", 12.6 # NT 13CR-80 tubing with 5 GLM's. Well Plan Summary RECEIVED NOV - 9 1994 ,A. iaska OiJ & Gas Cons. Commission Anchora:,,:- 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 10-3/4" CIRC. TEMP: 38°F PREFLUSH: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE' COLD SET III ADDITIVES: retarder WEIGHT: 12.2ppg YIELD: 1.92ft3/sx MIX WATER: 10.53 gps APPROX. 4/SACKS: 1000 THICKENING TIME: Greater than 4 hrs. @ 50°F TAIL CEMENT TYPE: CLASS G ADDITIVES' 2% A-7 +1 ghs FP-6L WEIGHT: 15.8ppg YIELD: 1.15ft3/sx APPROX. # SACKS: 375 MIX WATER: 4.95 gps THICKENING TIME: Greater than 3-1/2 hrs @ 50°F TOP JOB CEMENT TYPE: COLD SET II ADDITIVES: WEIGHT: 14.5 ppg APPROX. # SACKS' 250 YIELD: 0.96 ft3/sx MIX WATER: 3.89 gps THICKENING TIME: Greater than 2 hrs @ 50°F CENTRALIZER PLACEMENT: 1. Run 1 bow type centralizer per joint for the first 15 joints. 2. Place the centralizers in the middle of each joint with a stop collar. CEMENT VOLUME: 1. Lead slurry from TD to surface w/100% excess (less the tail slurry volume). 2. Tail slurry volume 375 sx (to cover 500' of casing shoe w/100% excess). 3. Top job volume 250 sx. Well Plan Summary RECEIVED NOV '~9 199~ A!aska Oil & Gas Cons. Commission Anchora,,. 7-5/8" LONGSTRING CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 7-5/8" CIRC. TEMP: 140°F PREFLUSH: 20 bbls fresh water SPACER: 70 bbb BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 3% A-2 + 0.4% FL-52 + 0.5% CD-32 + 1 ghs FP-6L WEIGHT: 11.0 ppg APPROX. # SACKS: 375 YIELD: 3.31 ft3/sx MIX WATER: 20.92 gps THICKENING TIME: 5 hrs FLUID LOSS: 150-250 cc/30 minutes FREE WATER: 0 cc TAIL CEMENT TYPE: CLASS G ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + 0.5% gel + 2 ghs FP-10L + S-400 WEIGHT: 15.7 ppg APPROX. # SACKS: 370 FLUD LOSS: < 50 cc/30 minutes YIELD: 1.17 ft3/sx MIX WATER: 4.85 gps THICKENING TIME: 2-1/2 to 3 hrs FREE WATER: 0 cc CENTRALIZER PLACEMENT: 1. Run 2 Turbulator per joint to 300' MD above top of Sadlerochit. 2. Run 1 straight blade rigid centralizer every joint 300' above and below the Cretaceous interval. (only where lead cement is being pumped to the Cretaceous) from 4256' to 6796'. 3. Run 1 solid body 7-3/4" x 9-1/4" centralizer or turbolator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix lead slurry on the fly, batch mix the tail slurry. CEMENT VOLUME: 1. Lead slurry to 300' MD above top of Ugnu (top of Ugnu at 4556' MD) 2. Tail slurry to 1000' MD above top of Sag River with 30% excess. 3. 80' MD 7-5/8", 29.7# capacity for float joints. Note: RECEIVED NOV - 9 1994 .~,i~ska Oil & Gas Cons. Commission Anchora.; Hydrocarbon bearing zones are identified in the Ugnu and Sag River intervals. Well Plan Summary 5-1/2" PRODUCTION LINER (CONTINGENCY) CEMENT PROGRAM - BJ SERVICES CIRC. TEMP: 140° F BHST: 220° F at 8800' TVDSS. PREFLUSH: 20 bbls fresh water SPACER: 70 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. CEMENT TYPE: CLASS G ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + 0.5% gel + 2 ghs FP-10L WEIGHT: 15.7 ppg YIELD: 1.17 ft3/sx MIX WATER: 3.58 gps APPROX. 4/SACKS: 110 THICKENING TIME: 45 min. @ Surface + 3-4 hrs@ 140°F FLUID LOSS: less than 50 cc/30 minutes @ 140°F FREE WATER: 0 cc at 45° angle. NOTE: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencies ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: 1. Run 2 right hand turbolators per joint in open hole, 2. Run 1 right hand turbulator per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 50 cc/30 min. or less. Report actual fluid loss on morning report. Displace @ 6-8 bpm. LINER CEMENT VOLUME: 1. Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 2. 5-1/2", 174/casing capacity below landing collar (80'). 3. 150' liner lap (6.875" x 5-1/2") 4. 200' of cement on top of the liner in the 7-5/8" casing. RECEIVED ?,!or - 9 i994 ~,~¢.a Oi~ & Gas Cons. Commission Anchor~:... Well Plan Summary g600 I : PRUDHOE BAY DR:[_L:[NG GROUP R-36 (P2) VERTICAL SECTION VIEW Section at' 63.93 TVO Scale.' ~ ~nch = ~200 feet Oep Scale' J inch = ]200 feet ' i h]umbsrg~r - . . . , ii ....................... , . Flerker Identification 140 3KB §EETN INCLN ~ ,i i i Al K~ 0 0 0 0.00 . ' ~ Bi KDP/BU~LO ~ 5/]00 ~900 1900 0 0.00 I i · i . ~ C) , 3104 3049 309 30.09 ;-- ~066 ~19 30,59 .__~._ ,, ................. i ...................... ~ Ol 8ND OF 2.51100 BUILD ! %~~- ~: E) DROP 1,5/~00~ 8435 7639 3022 30,59 I ' i i ¢) ?-5/8" CASINu POINT 9681 8795 3471 il,89 ' / I ~ ! S] ....... TARGET ....... 9808 6919 3485. ~0.00 ) ~ ; H] TD 10140 9247 3553 ~O.OD , ~ ~ ~ ! i blOT APP[ iOMED_F(')R , I I ~ ' ' ~ ' X ~ ' : ~EC JTION , ___J ........ X : : P~N ~¢ / - - ~ .... I ....... '~l -'l ......... ' .................... '1- ~ IN ~ ! -- i ! .............. . -, ..... , ...... 4 ............ i. _~. _ ~ ..... ; ........... I I : - I i ,,, ,, ' , ~ ~ , n ~'~,~ ~,~ :."N¢=~¢ ' ~' ' '; ........... ~' .......... NT ..... r ..... ! ........... / ' ' ; t ..... ~ ' unV -; - ,f ..... , ~ _. . ............... ~ ................. ........ ~5 k,~Sk~ 0il & 13as C°ns~C0mmiss 0~ :' I" ' ~a~ I ~~ ~ ~ ~ [ ........ ' t ~ : [ ' II , ~' ' ........ '-- " -- ======================== =;;;;~;~' :====--i ........... ; .... ': ~;,~(:::;::::::::::::::::::::::::::::::::::::: :~ ~ : , , ~ .~! .::': .::[ _':_: __.!'.. 1 ...... -t I -. -I 60o '..200 Jeoo 24o0 aooo %00 4200 ~eoo 54oo sooo 6600 7200 Sect ~on Departure I I . I [ . .- ill ? i · ..... i' ".I "'"':' ..... : ~'.:: ' .: : I'" ii i i ":" ';i":,'-: I · - .! . ... .. . ~ ... · .- .-. . . '. . : .. :' ' ... · c- i'S',/3 ' ..LS;~ -> 'o0~: ooa~' ooos oo~a~ Ooga 'oo,~.a a.o;~,?. ~]ooa o~il~ 'o~q'~ O'L~";,'~ "00~ ooi)~ 'ooi~ '0'O9' Oi];~, 00~ "O' ' 'O0~ ' ~ NOt J-FIZ']X--:t i , uoJ.._.:..... ,~_ ._,,,, ~ - rl'q/~.,""',,~cr,4,u ~~, · , u..., ,~ -, NMId ,k_Li-]l ~] t S'~,":t._-i ~ O'r, ~ ~ ........ :. ~.,... ..... ~ , ....~ · ! .......... · .. . , ~ - [6[~ $9qi OPIOI j Ol-,I~: 9CGf: BOg6 .......... l. agt:lYJ. BJ[[ gS§[ [995 £NIOd 9NIS¥3 .8, ~ ~'~ZZ 93£[: §'~t,9 ,gO1./§' 1~ , ,, ' ' ' _rlg~ t]IrJ E~IE: O'lIrl8 001:/~i'~ -lO /.i~ gel. POI, E: .- O ,0 006[. Od,'l[/q' [~ j ..... 0 0 0 ................................................................... N/-] S/N (]N UOC. 1B3! ~ .~luaPI - l~6/ZO/J[ ........ L :laa~ 00[,: LIeUt. [ ........ ...................... I ........... ] ~B8'6Z "NO]:L~, d~OU9 9N I"~'i'~ Z I::la I al (H ,,a/g- L JB;IJEH N,I',tYU( 11133a N3IA N¥-ld ................................................ ' (~d) ........ .g~.---~-.- WELL PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. N 10. Operator has appropriate bond in force ........ N 11. Permit can be issued without conservation order .... N 12. N 13. N Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING APPR D~TE 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all kno~ productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & pe~afrost .... ~ N 20. Adequate tankage or rese~e pit ............. N 21. If a re-drill, has a 10-403 for abnd~t been approved. .~~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid progr~ schematic & equip list adequate .~ N ~'~ 25. BOPEs adequate ............. ~ ...... ~ N 26. BOPE press rating adequate; ~est to ' ~~ psig.~ N 27. Choke manifold complies w/~I ~-53 (May 84) ...... ~~ 28. Work will occur withou~ operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y ~ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Colents/Instructions: Z ~'-heklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, 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. , Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6311.00 BRAD ESARY SEE REMARKS REMARKS: OPEN HOLE R - 36 (43-32-12-13) 500292252200 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 05-DEC-94 RUN 2 RUN 3 32 12N 13E 781 3629 49.10 47.60 20.10 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 9824.0 6.750 10162.0 DIFL/AC/ZDL/CN/GR. CIRCULATION STOPPED AT 2100, 29-NOV-94. LOGS WITNESSED BY: DON DUBOIS & STEVE JONES. THE SP CURVE RESPONSE WAS NOT NORMAL BUT DOES REPEAT. CALIPER VERIFICATIONS WERE PERFORMED IN CASING. NEUTRON LOG PARAMETERS: OPEN HOLE SECTION SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. NEUTRON LOG PARAMETERS: CASED HOLE SECTION SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS ACTIVE CASING THICKNESS = 0.375" CEMENT THICKNESS = 1.125" SALINITY = 0.00 PPM. R- 36 PRUDHOE BAY RECEIVED D£C 2 ] 1994 Alaska Oil & Gas ~..~ /%, Run 1' 30 - November - 1994 DIF LIAC IZDLIC NIGR 'MICROFILMED,,,, ATLAS Atlas Wireline Services 1801 0136 PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9801.0 10053.0 BCS 9801.0 10107.0 DIL 9801.0 10136.0 SDN 9801.0 10077.0 2435 9801.0 10059.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) all runs merged; no case ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH DT LL8 ILD NPHI RHOB 9816.0 9815.5 9819.0 9818.5 9826.5 9826.5 9826.5 9832.0 9832.0 9840.0 9840.0 9840.5 9839.5 9842.0 9841.5 9841.5 9842.5 9841.5 9847.5 9847.0 9848.0 9848.5 9847.0 9853.0 9853.0 9853.0 9853.0 9857.5 9858.5 9859.5 9860.0 9865.0 9865.0 9893.0 9892.5 9892.5 9892.5 9903.0 9903.5 9903.5 9903.5 9904.0 9904.0 9904.5 9904.0 9914.5 9915.5 9917.5 9918.0 9924.0 9923.5 9929.5 9930.0 9929.0 9929.0 9934.0 9934.0 9934.5 9935.0 9934.5 9934.5 9937.0 9937.0 9937.5 9938.0 9942.0 9942.5 9949.0 9949.5 9949.0 9949.5 9949.0 9952.0 9952.0 9962.5 9963.0 9963.0 9962.5 9965.0 9966.0 9965.5 9966.0 9967.5 9967.5 9971.5 9971.0 9971.5 9974.0 9974.0 9974.5 9974.5 9978.5 9978.5 9979.0 9979.0 9980.5 9983.0 9986.5 9988.0 9986.0 9987.0 9990.0 9993.5 9995.5 9995.5 10002.5 10003.0 10019.5 10019.5 10020.0 10022.5 10024.0 10024.0 10026.0 10027.5 10034.0 10039.0 10041.5 10047.0 10051.0 10066.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 3 BCS 1 3 DIL 1 3 SDN 1 3 2435 1 3 $ REMARKS: 9983.5 10026.5 9987.5 9993.5 10022.5 10039.5 MERGE TOP 9801.0 9801.0 9801.0 9801.0 9801.0 OPEN HOLE portion of MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LLS. ILM, RT, & DI WERE SHIFTED WITH ILD. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. 9980.0 9986.0 9990.5 9994.0 10019.5 10027.0 10033.5 10040.5 10046.0 1O050.0 10066.0 MERGE BASE 10053.0 10107.0 10136.0 10077.0 10059.0 CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT / ??MATCH3. OUT / ??MATCH4. OUT / ? ?MATCH5. OUT $ : BP EXPLORATION (ALASKA) : R - 36 (43-32-12-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: API API API API Name Tool Code Samples Units Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 2 DT BCS 68 1 US/F 3 TEND BCS 68 1 LB 4 TENS BCS 68 1 LB 5 LL8 DIL 68 1 OHMM 6 ILM DIL 68 1 OHMM 7 ILD DIL 68 1 OHMM 8 RT DIL 68 1 OHMM 9 DI DIL 68 1 IN 10 SP DIL 68 1 MV 11 MTEM DIL 68 1 DEGF 12 RHOB SDN 68 1 G/C3 13 DRHO SDN 68 1 G/C3 14 PEF SDN 68 1 BN/E 15 CALl SDN 68 1 IN 16 NPHI 2435 68 1 PU-S 17 FUCT 2435 68 1 CPS 18 NUCT 2435 68 1 CPS 4 4 67 465 06 6 4 4 84 653 71 5 4 4 20 789 90 0 4 4 20 789 90 0 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 98 211 23 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 55 Tape File Start Depth = 10158.000000 Tape File End Depth = 9801.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13586 datums Tape Subfile: 2 233 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9385.0 2435 9385.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9390.0 9406.5 9430.0 9484.5 9500.5 9510.5 9519.0 9534.0 9539.0 9551.0 9561.5 9576.5 9598.0 9600.5 9605.0 9611.5 9625.5 9632.5 9635.5 9656.0 9658.0 9671.0 9674.0 9676.5 9691.5 9696.0 9707.5 9719.0 9759.5 9764.0 9768.5 9791.0 $ REMARKS: STOP DEPTH 9801.0 9801.0 ......... EQUIVALENT UNSHIFTED DEPTH NPHI 9390.0 9406.5 9430.0 9484.5 9500.5 9510.5 9519.5 9533.5 9538.5 9551.0 9562.0 9577.0 9598.0 9600.0 9605.0 9612.0 9625.0 9632.5 9635.5 9656.5 9658.5 9671.0 9674.0 9677.0 9691.5 9696.0 9707.5 9719.0 9759.0 9764.0 9768.5 9791.0 CASED HOLE portion of MAIN PASS. FUCT, NUCT, TEND, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH6. OUT $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : R- 36 (43-32-12-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 2 NPHI 2435 68 1 PU-S 3 FUCT 2435 68 1 CPS 4 NUCT 2435 68 1 CPS 5 TEND 2435 68 1 LB 6 TENS 2435 68 1 LB 4 4 08 501 10 0 4 4 98 211 23 4 4 98 211 23 1 4 4 98 211 23 1 4 4 19 912 29 5 4 4 19 912 29 5 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 24 Tape File Start Depth = 9801.000000 Tape File End Depth = 9382.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5874 datums Tape Subfile: 3 86 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 3 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9383.0 10064.5 AC 9798.0 10119.0 DIFL 9796.0 10148.0 ZDL 9798.0 10088.0 2435 9383.0 10066.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL TEMP KNJT PCM KNJT AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE KNUCKLE JOINT PULSE CODE MODULATOR KNUCKLE JOINT BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 30-NOV-94 FSYS JlV2 BETA RELEASE 4 2100 29-NOV-94 625 30-NOV-94 10162.0 10139.0 9385.0 10136.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 2806XA 3921NA 3506XA 3921NA 1609EA/1603MA 1503XA 6.750 9824.0 9801.0 LSND 8.90 41.0 MUD PHi FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : R - 36 (43-32-12-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA 10.9 6.8 180.7 2.530 .850 3.210 .000 1.750 .000 THERMAL SANDSTONE 2.65 .000 1.5 56.0 180.7 56.0 .0 56.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS 4 4 06 969 49 6 4 4 48 852 89 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 522 10 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 40 467 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 21 SSN~ 2433 68 1 CPS 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 283 974 BYTES * 84 Tape File Start Depth = 10158.000000 Tape File End Depth = 9382.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 81897 datums TaPe Subfile-. 4 367 records... M~nimum record length: 62 bytes Makimum record length: 974 bytes Tape Subfile 5 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 4 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9796.0 10022.0 AC 9796.0 10077.0 DIFL 9796.0 10106.0 ZDL 9796.0 10046.0 2435 ~ 9796.0 10024.0 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION MIS MASS ISOLATION SUB MODL MODAL SUB GR GAMMA RAY CN COMPENSATED NEUTRON ZDL Z-DENSITY TEMP TEMPERATURE KNJT KNUCKLE JOINT PCM PULSE CODE MODULATOR KNJT KNUCKLE JOINT AC BHC ACOUSTILOG DIFL DUAL INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): 30-NOV-94 FSYS J1V2 BETA RELEASE 4 2100 29-NOV-94 708 30-NOV-94 10162.0 10139.0 9385.0 10136.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 2806XA 3921NA 3506XA 3921NA 1609EA/1603MA 1503XA 6.750 9824.0 9801.0 LSND 8.90 41.0 10.9 6.8 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION-(ALASKA) : R - 36 (43-32~12-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA 180.7 2.530 .850 3.210 .000 1.750 .000 THERMAL SANDSTONE 2.65 .000 1.5 56.0 180.7 56.0 .0 56.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR AC 68 i GAPI AC AC 68 i US/F CHT AC 68 1 LB TTEN AC 68 i LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 i OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 06 969 49 6 4 4 48 852 89 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 522 10 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 40 467 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 117 974 BYTES * Tape File Start Depth = 10116.000000 Tape File End Depth = 9796.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34057 datums Tape Subfile: 5 199 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile'6 is type: LIS 94/12/ 5 01 **** REEL TRAILER **** 94/12/ 5 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 5 DEC 94 1:39p Elapsed execution time = 14.34 seconds. SYSTEM RETURN CODE = 0