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Home My WebLink About189-0757. 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 L3-01 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 189-075 50-029-21959-00-00 14375 Conductor Surface Intermediate Production Liner 9172 80 5225 13553 1064 7274 20" 13-5/8" 9-5/8" 7" 5157 40 - 120 39 - 5264 36 - 13589 13304 - 14368 40 - 120 39 - 3994 36 - 8640 8463 - 9168 13935 , 13938 470 2260 4760 7020 7274 1490 5020 6870 8160 0 - 0 4-1/2" 12.6# L-80 34 - 13579 0 - 0 Structural 4-1/2" Baker Mod DB Perm , 13244 , 8427 No SSSV 13244 8427 Bo York Operations Manager Andrew Ogg Andrew.Ogg@hilcorp.com (907) 659-5102 PRUDHOE BAY, LISBURNE 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 0034631 34 - 8634 0 0 0 0 0 0 0 0 0 0 N/A 13b. Pools active after work:LISBURNE 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 By Grace Christianson at 8:52 am, Aug 22, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.08.21 18:57:52 - 08'00' Bo York (1248) RBDMS JSB 082824 DSR-8/26/24WCB 10-3-2024 ACTIVITYDATE SUMMARY 7/22/2024 T/I/O = 750/650/240. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Austin McLeod. Pictures taken. SV, SSV = C. MV = O. IA & OA = OTG. 09:00 Daily Report of Well Operations PBU L3-01 Reviewed By: P.I. Suprv Comm ________ :ZϬϴͬϯϬͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐ^DϮϰϬϳϮϮϭϵϬϬϬϰ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϳͬϮϮͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƵƐƚŝŶDĐ>ĞŽĚ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϵͬϭϯͬϭϵϵϰ dƵďŝŶŐ͗ϳϱϬ /͗ϲϱϬ K͗ϮϰϬ KƉĞƌĂƚŽƌ͗,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ͕>> KƉĞƌĂƚŽƌZĞƉ͗ŶĚƌĞǁKŐŐ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϳͬϭϲͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ tĞůůEĂŵĞ͗WZh,KzhE>/^>ϯͲϬϭ WĞƌŵŝƚEƵŵďĞƌ͗ϭϴϵϬϳϱϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ ^^sŽƉĞŶĞĚĨŽƌƉƌĞƐƐƵƌĞƐ͘ZƵƐƚǇͬĐŚŝƉƉĞĚƉĂŝŶƚ͘EŽůĞĂŬƐ͘&ůŽǁůŝŶĞƌĞŵŽǀĞĚ͘ůůǀĂůǀĞƐŽƉĞƌĂďůĞ͘ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ WĂĚŐƌĂǀĞů ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ ůĞĂŶͬĚĂŵƉŐƌĂǀĞůͲŶŽƐŚĞĞŶƐ͘ ŽŵŵĞŶƚƐ WĂĚŵĂƉƵƐĞĚ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ EŽŝƐƐƵĞƐ͖WŚŽƚŽƐ;ϭϬͿĂƚƚĂĐŚĞĚ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗ŽŵƉůĞƚŝŽŶZĞƉŽƌƚ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ &ƌŝĚĂǇ͕ƵŐƵƐƚϯϬ͕ϮϬϮϰ 9 9 9 9 9 9 9 9 9 2024-0722_Suspend_PBU_L3-01_photos_am Page 1 of 5 Suspended Well Inspection – PBU L3-01 PTD 1890750 AOGCC Inspection # susSAM240722190004 Photos by AOGCC Inspector A. McLeod 7/22/2024 2024-0722_Suspend_PBU_L3-01_photos_am Page 2 of 5 2024-0722_Suspend_PBU_L3-01_photos_am Page 3 of 5 2024-0722_Suspend_PBU_L3-01_photos_am Page 4 of 5 2024-0722_Suspend_PBU_L3-01_photos_am Page 5 of 5 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:189-075 6.50-029-21959-00-00 PRUDHOE BAY, LISBURNE 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 14375 7274 5157 13244 13935, 13938 7274 8427 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 40 - 120 40 - 120 1490 470 Surface 5225 13-3/8" 39 - 5264 39 - 3994 3450 / 5020 1950 / 2260 Intermediate 13553 9-5/8" 36 - 13589 36 - 8640 6870 4760 Production Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 34 - 13579 34 - 8634 13244 8427Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker Mod DB Perm Packer Liner 1064 7" 13304 - 14368 8463 - 9168 8160 7020 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 SUSP5 SPLUG 16. Well Status after work:OilGas 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 measured9172 Sundry Number or N/A if C.O. Exempt: 320-237 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 028322 & 034631 PBU L3-01 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 8:28 am, Jun 19, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.17 14:04:49 -08'00' SFD 6/23/2020 RBDMS HEW 6/19/2020 DSR-6/22/2020MGR26JUN20 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:189-075 6.API Number:50-029-21959-00-00 PRUDHOE BAY, LISBURNE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 034631 Property Designation (Lease Number):10. 8. PBU L3-01 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 14375 Effective Depth MD: L-80 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): 9172 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 13244 / 8427 No SSSV Installed Date: Liner 1064 7" 13304 - 14368 8463 - 9168 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 39 - 5264 39 - 3994 14. Estimated Date for Commencing Operations: BOP Sketch 40 - 120 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker Mod DB Perm Packer None 4-1/2" 12.6#34 - 13579 Production 7274 5157 7274 13935, 13938 40 - 120 470 13-3/8" 9-5/8" Contact Phone:+1 9075644711 Date: 4760 80 149020"Conductor 1950 / 2260 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 5225 3450 / 5020 Intermediate 13553 36 - 13589 36 - 8640 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 2:21 pm, Jun 02, 2020 320-237 Mcmullen, John C Digitally signed by Mcmullen, John C Date: 2020.06.02 13:19:27 -08'00' X ; ADL0028322 (Surface) DLB DLB 6/3/2020 DSR-6/2/2020MGR12JUN20 10-404 *Per 20 AAC 25.110 Suspended Wells: (e) Next inspection shall be conducted 24 months before September 30, 2025. *Variance request to 20 AAC 25.110 Suspended Wells (c) is approved Yes 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: Lisburne Well L3-01 (PTD #189075) Application for Renewal of Existing Suspension (10-403) Dear Mr. Price, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Lisburne well L3-01 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 Lisburne well L3-01 was suspended on 09/13/1994. It is located on a pad with active wells and/or service wells. 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 7274’ in the 4-1/2” tubing. Based on these conditions and the inspection on 09/15/2019 Lisburne well L3-01 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 Lisburne well L3-01 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 Lisburne Well L3-01 (PTD #189075) Technical Justification for Renewal of Suspended Status May 26, 2020 Well History and Status Lisburne well L3-01 (PTD # 189075) was suspended on 09/13/1994 after a casing leak was identified allowing crossflow from the Cretaceous formation to the Wahoo formation. 47 bbls of 13.5 ppg class "G" cement was placed in the well from 13,903' to 12,914' on 09/15/1994. Slickline tagged TOC at 12,920' SLM on 09/18/1994. IA x tubing communication was discovered during the pressure test to verify the cement plug. On 09/25/2010 7' of perforations were shot through the tubing at 12,820' - 12,827'. 286 bbls of 14 ppg class "G" cement was pumped down the tubing and into the annulus, with estimated cement in the tubing x 9-5/8" casing annulus from 12,827' - 7,480' MD. A slickline drift on 10/07/1994 tagged cement in the tubing at 12,817'. A State witnessed pressure test on the tubing to 1600 psi and on the annulus to 1500 psi passed. On 10/23/1994 the tubing and 9-5/8” casing were perforated from 11,680' - 11,690' and 81 bbls of 15.7 ppg class "G" cement was squeezed into the formation and laid in the tubing. A slickline drift confirmed TOC at 7,273' on 10/25/1994. A State witnessed slickline tag to 7,274' and pressure test of the tubing and the 9-5/8” casing to 1500 psi was performed on 11/07/1994. The well casing is mechanically sound as proven by tubing and casing pressure tests on 11/07/1994. 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 Lisburne well L3-01 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 = 600/600/250 psi. Request BPXA requests approval for renewal of the existing suspension status for L3-01. 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. 4 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspend Well Inspection 13 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number:, 189-075 3. Address: P.O.Box 196612 Anchorage, Development I1 Exploratory El AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: - 50-029-21959-00-00 7. Property Designation(Lease Number): , ADL 0034631 8. Well Name and Number: LISB L3-01 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: R F f Total Depth: measured 14375 feet Plugs " , measured 7274 feet true vertical - 9172 feet Junk measured 13935/13938 feet AUG; i G 2 2015 Effective Depth: measured 7274 feet Packer measured 13246 feet true vertical 5157 feet Packer true vertical 8428 feet G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 40-120 40-120 1490 470 Surface 34/5192 13-3/8"68#K-55/L 39-73/73-5265 39-73/73-3995 3450/5020 1950/2260 Intermediate 13555 9-5/8"47#L-80 36-13591 36-8642 6870 4760 Production Liner 1072 7"29#L-80 13298-14370 8459-9169 8160 7020 Perforation Depth: Measured depth: 13706-13799 feet 13807-13884 feet 13920-13945 feet 13945-13950 feet 13950-14030 feet True vertical depth: 8717-8780 feet 8785-8837 feet 8861-8878 feet 8878-8882 feet 8882-8936 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 36-13580 36-8635 Packers and SSSV(type,measured and 4-1/2"Baker Mod DB Perm Packer 13246 8428 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: SI Subsequent to operation: SI 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP m SPLUG 0 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: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature )1��_r/ C _, Phone +1 907 564 4424 Date e/c //c- Form 10-404 Revised 5/201515 V T . 61/0//5- Submit Original Only 4 `n6e(l,) RBDMS AU6 31 BS • • U (0 C a) N U L a) a) a) C CL C U C- N (B O O O U tLo N O N II C O >- m 0 E R{ Q SiE 2 a) U Q A is us >,Q 2 O w Z C Too p IL O M 00 c O m CU — C J O O U) U Qj CD Q L- W >1 a) 0 asC N (6 -O coa) C n 3 U U) T 0 U O 5 Caw' w <Q w a Lo H >- O co H co U o • Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UN LIS L3-01 Field/Pool: PRUDHOE BAY/LISBURNE OIL Permit#(PTD): 1890750 API Number: 50-029-21959-0000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 9/13/1994 Surface Location: Section: 22 Twsp 11N Range: 15E Nearest active pad or road L3-Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools 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: Clean, active pad Pad or location surface: graded gravel Location cleanup needed none Pits condition. N/A Surrounding area condition: Clean Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition. Good Photographs taken (#and description) (1)well area 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. McEvoy WH, CIW tree, all valves functional, casing open to gauge Cellar description, condition, fluids backfilled with gravel, SSV hydraulic fluid drum connected and empty Rat Hole: N/A Wellhouse or protective barriers steel barricade Well identification sign. Yes, correct Tubing Pressure (or casing if no tubing): 700 psi Annulus pressures: IA= 500 psi OA=240 psi Wellhead Photos taken (#and description): (2)wellheadand tree Work Required none Nip Operator Rep (name and signature) Whitney Pettus AOGCC Inspector: Bob Noble Other Obseryer Ryan Hayes Inspection Date 8/8/2015 AOGCC Notice Date: 8/8/2015 Time of arrival: 9:35 AM Time of Departure: 10:00 AM Site access method: Truck . • • • j n u , 0 rc t r 03 w D O 6 v cr s co w w U r r: m c w ( > u -0 o N) .1 K U i N 74 OJ N O r 1 0 - U1 ® y s -O C t0 X r rt a rriri" ) ro i o .r wLwanw o• w WWNrWJ r "'..�, �n w F. ? 4::, N OO O > •'C' O O N '4 w 0 a - i st, r..) "z m \\\\ .a• CU1!: / W C N n g xam > y o n A i O • Q°i f.1 r� A ro C� D o g m r m m _ -o o5 m m r- c w z m y A O A m m a F - 0 j} m 2 rEt o W N js Fl. z r o O A O n g e. m A r 9' v / O °a A w ern c cf a , c J r•'r m P. r AyA r > A' i.�. 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' .. • ., '.' -... . . , ' . ' ...., .. .• . ''. ' ........ ,. ... ...'. ''.. - ' .. ' • '-•••-• .' . . , . ... .. .., .... • 4 ' . . .. , • .. .. '... . . , • . ,, •,, .' . - I ,1 '1E ELL: L31.111°1 I! r OWNER Lisburne Unit 11111116 1 /1111111111ir OPERATOR nitBP Exploration (Alaska) Inc. `, API NUMBER ' .7"---- rt50-029-21959-00-00 ...iii .E ,`112.- /Es►*�# SUR. LOCATION NW 1/4, Sec. 22, T11N, R15E DRILLING PERMIT 189-07$ a RT mowr=►. -- fI. .�- -. ... ��+ +"n « a; y". �447. .. � - _ .... -. r 6 � • `.h, 35003500 . c„ �, • • 2. I Do e ,. A . r • y r siTir -'''7*. ': ''' ', ' M r • yy' e+re c i i t 3A_ • ! r. �‘•�‘��e •,\\��`N�t, :roe 4 \NN. \:\ s\NNL:t... ,,. ill' III ' , x Plot ' ..„ . . „, , g, , ,.. _ V 40. Alt .I4 , ,, , . ,,,,, ,. ; ,. 1 1 ., . It'ii' i'W: '':.' ' ' ', t 3 �f �., WELL: L3-01 r`�'" MN OWNER Lisburne Unit u,: � OPERATOR i;_ BP Exploration(Alaska)Inc. API NUMBER ...... ... 50-029-21959-00-00 aeliumminimr i^ � SUR.LOCATION ;„,.„7--,4i.,;5 • DRILLING PERMIT 89 175'Sec.22,T11N,R15E �, 189-075 - .. . i. . , t • • • a x ,.” 8 'r t $ b A III 111111 TREE= McEVOY WELLHEAD= McEVOY 0 SAFETY NOTES: COMMUNICATION FROM ACTUATOR= AXELSON - 9-5/8"CASING TO THE CRETACEOUS. KB.ELEV= SUSPENDED.SEE WELL FILE. BF ELEV= KOP900' •A .I 61 • 8200 Datum MD= 14065' I 2304' H OTIS SSSV HQR BV LN, D=3.81" I Datum TVD= 8900'SS 13-3/8"CSG,68#,L-80, D=12.415" —1 5264' HAI GAS LIFT MANDRELS ST tufa TVD DEV TYPE VLV LATCH PORT DATE 1 3256 2813 5 FMHO RK 2 7108 5065 56 FMHO RK FT 3 10278 6760 55 FMHO RK Minimum ID = 3.725' @ 13566' 4 12431 7959 56 FMHO RK 4-1/2" OTIS XN NIPPLE 5 13131 8360 54 FMHO RK TOP OF CEMENT H 7274' , 111 81 111 1111 1 11 '. • 4 1 L 13240' —9-5/8"BAKER DB PKR, ID=4.0" 11111 1i TOP OF 7"LNR —I 13284' ��1/111.. 1i1 � 111111111 111 1 111111 11144 13566' —14-1/2"OTIS XNNIP, ID=3.72" 11i111i 4-1/2"TBG-IPC, 12.6#, L-80,0.0152 bpf, D=3.958" —I 13578' ( k111�141� 13578' I I4-1/2"BAKER SOS, ID=4.0"1 1111 1 1111 111111 13542' HELMD TT LOGGED 11/29/89 J 1111111111111 1111111111111 111111 —41A 11/11111i111 9-5/8"CSG,47#,L-80, 0.0732 bpf, ID=8.681" 1 13589' 1111111 1111/11111 11/1/1/1 1111111 111 ' 1111111' /11111 1111 1111111' 11111 N PERFORATION S UMMA RY 111 1111 111 14. 1 1111111 REFLOG:Z-DENSITY/CN ON 08/12/89 1/111/111/111 ANGLE ATTOP PERF:48@ 13706' 1111111^ Note:Refer to Roduction DB for historical perf data 111/1/14 SEE SPF INTERVAL Opn/Sqz DATE 11111/11144 3-3/8" 6 13945-13950 0 10/20/89 1111111111111 3-3/8" 2 13920-14030 0 11/29/89 1/1�11. /1 111 •.11 3-3/8" S 13807-13884 0 01118/90 11�= v1.! 13935' HSANDANDRRFBALLS 3-3/8" *S 13706-13799 0 01/18/90 111, .11111111 11111111 Selected Shots 11111 11111111111, 1111111111 411 ..1 AA •A 13938' —I DEFLATED BRIDGE RUG 41i1'1A1/1I IPBTD H 14320' A1AI11•411 A% 1*1*Iy*11111 111111111111 7"LNR,29#, L-80,0.0371 bpf, ID=6.184" H 14368' v1•1•IA •G•A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/24/89 ORIGINAL COMPLETION 03/04/07 RL DATUM MD WELL: L3-01 11/07/94 WELL P&A'd PERMIT Na: 89-75 12/09/00 SIS-QAA CONVERTED TO CANVAS AR No: 50-029-21959-00 03/13/01 SIS-MD FNAL SEC 22 T11 N R15E 09/30/01 RN/TP CORRECTIONS BP Exploration(Alaska) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/08/15 Inspector: Bob Noble Operator: BPXA Well Name: PBU L3-01 Oper.Rep: Ryan Hayes • PTD No.: 1890750 - Oper.Phone: 659-5766 Location Verified? Yes Oper.Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 09/13/94 Date AOGCC Notified: 08/06/15 • Sundry No.: 194-177 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 700 Photos Taken? Yes IA 500 OA 340 Condition of Wellhead: Wellhead was in good clean condition with no signs of leaks or drips.Wing valve was removed and flow cross was blinded,All other lines were blinded.Gauges were installed in proper places.SSV was blocked open. Condition of Surrounding Surface Location: The ground looked to be good clean gravel.The drum for the SSV was empty.Wellhead was protected with a guard rail. Follow Up Actions Needed: none Comments: none SCANNEDJUL1 8 2016 _ Attachments: Photos(5) J REVIEWED BY: Insp.Supry J - 'I I Z Inc Comm PLB 12/2014 2015-0808_Suspend_PBU_L3-01_bn.xlsx • • Suspended Well Inspection—PBU L3-01 PTD 1890750 Photos by AOGCC Inspector B. Noble 8/8/2015 1 WELL: L3- 01 ii OWNER Lisburne Unit OPERATOR BP Exploration (Alaska) Inc. ex API NUMBER w5:-.6(.)229- 1959-00-00 '' SUR. LOCATION 1/4, Sec. 22, T11N, R15E DRILLING PERMIT 19-075 =rr rs Am WO 1142 amu„ - imp11111 , illiwor . j n -.;21':.:'`.. :2.',•-,''' 7 s: '.."-7—.t- ,:-":" ' . to' 4„6,6,9 '°-Z>\'‘?;°7 fo -*-$f ' 9 T \,,p,'� -,..•>,,.� -,), ,,,,,, ,,,,,..: . . .. ..1 ,,,, , .<.4, ,.. .. , .19 A'IP, ' a 'a. v 1 • f . '. �+v r**soh m ''m i. '.4.!' `,` ' w r s E 1. 2015-0808_Suspend_PBU_L3-01 photos_bn.docx Page 1 of 3 • 0 1 . 1 . ,. ., ,,., 7'A • ,. - ... -., . . . .....4 = ...... .. ,410x.„..........„.. ..,,,,..„,.. .,...4...: „.....4,...i.a ...._. Aitift -V 417 =--.' 111111k ' ,;;;...J125 ... . • .=, , Pia Ito :' • ' . . -0 I ... En , .,....„.. ; Irj 0. . cli r ' ' 1 - I 0 [ 14 = ?c, -I •• t 0.0 cts -,„ I 0_, a.) sa. ':'.4' . '' . ' 0 ce)I oo cD, oo *- !'44 9 ,--, c) c‘i 1$ J ----•". ' eit.. 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""' ""'"'"'""""r vv,,, ,--,,s,.or,., PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly Bre~athan Lowell [] TO RE-SCAN Date'~~ Isly~ Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 , N AUG () 2 ZOlC Mr. Jim Regg 81-0 76' Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 P` Subject: Corrosion Inhibitor Treatments of GPMA Lisburne 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L3 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, Gerald Murphy, at 659 -5102. Sincerely, 4 )(11L—c- r` )‘ Mehreen Vazir 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) GPMA Lisbume 3 Date: 0319812012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date "- L3-01 1890750 50029219590000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3-02 1861540 50029216440000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-05 1851950 50029214210000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-08 1831430 50029210190000 3.0 N/A 3.0 N/A 27.20 11/29/2011 L3-11 1852310 50029214520000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-12 1861610 50029216510000 Dust Cover N/A 0.0 N/A N/A 3/8/2012 L3-15 1852660 50029214760000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-18 1861670 50029216570000 0.0 N/A 0.0 N/A 11.90 11/20/2011 L3-19 1852860 50029214940000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-22 1861750 50029216630000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-23 1853060 50029215130000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-24 1861820 50029216700000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-28 1890660 50029219550000 PMA 12/93 NA NA NA NA NA L3-30 1861850 50029216730000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3-31 1860340 50029215440000 0.0 _ N/A 0.0 N/A 8.50 11/29/2011 • • ~~a~[~ 0~ Q~Q~~{Q /~..~~...~o~u~ Gary Preble Data Management Engineer BP Exploration (Alaska), Inc. •~~~~,, y , P.O. Box 196612 ~ _ -- ~ `' ..V Anchorage, AK 99519-6612 ~® Re: Prudhoe Bay Field, Lisburne Oil Pool, L3-01 1 ~ ~ ._- Sundry Number: 310-281 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 r~ 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 September 1, 2010 by ~~ Mr. Daniel Seamount, Chairman ~~ ~~ 1 ~~1Ci Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ,~~: ~ r~rt ~ r~ 14 ~;~iss°°'~ Anchorage, Alaska 99501 t~fi~~ `~~~` Subject: Lisburne Well L3-01 (PTD #1890750) Suspended Well Inspection Report (10-404) Application for Renewal of Existing Suspension (10-403) Dear Mr. Seamount, BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Lisburne well L3-01 on 8/21/10. 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)). We believe this information demonstrates that the well is mechanically sound. Specific attachments include: • Suspended Well Site Inspection form documenting the well pressures and site condition, witnessed by an AOGCC inspector • Wellbore diagram illustrating the current configuration of the well • Pad map and aerial photo showing well location and other wells within one- quartermile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Lisburne well L3-01 was suspended on 9/13/94. It is located on a pad with active producing 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 Lisburne well L3-01 is mechanically sound and secure and meets 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, ~~ ~ i 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 Michael Hibbert Gary Preble STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISSI~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 .~~~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pooi^ 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 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Q , Exploratory ^ 189-0750 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21959-00-00 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 ^ L3-01- 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-034631 ~ PRUDHOE BAY Field / LISBURNE 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): 14375 - 9172.34- 7274 ~ 5156.57 ~ 7274' TOC 13935 13989 Casing Length Size MD TVD Burst Collapse Structural Conductor 115 20" 91.5# H-40 SURFACE 115 SURFACE 115 1490 470 Surface 5264 13-3/8" 68# K-55/L-80 SURFACE 5264 SURFACE 3994 3450/4930 1950/2270 Intermediate 13590 9-5/8" 47# L-80 SURFACE 13590 SURFACE 8641 6870 4760 Production 1064 7" 29# L-80 13304 14368 8463 9168 8160 7020 Liner Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 URFACI 13579 Packers and SSSV Tvoe: 9-5/8" BAKER DB PKR Packers and SSSV MD and TVD fft): 13240 8426 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q' Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/15/2010 Oil ^ Gas ^ WDSPL ^ Suspended O'~ 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 ry Preble Title Data Management Engineer Signature Phone Date 564-4944 9/1/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY witness Sundry Number: ~ ~ O ` ~' resentative ma Commission so that a re diti l Notif C f y p approva : y on ons o Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ , ~'' ~ "td ,~ III ~~rn ~-~ ~`u~ ~ l4.Ge-h,.e,~ Q~D~rov~ ~ ~ Subsequent Form Required: ~ ~ / ~ ~i1S .~~~~ - 6 ~{~~~i~ ~«~ ~ ~8~ '8`sn» ~`t~ti)11i1SSIJ' ~ •il~~"1 ~I' ~f3 APPROVED BY h 1 ~ ~ ~ t,~ / tI `^~ Approved by: COMMISSIONER THE COMMISSION f Date: `" `F~BDMS SEP 0710 Form 10-403 Revised 1/2010 O R I G I N A L ~ ~~Z'lU Submit in Duplicate B L3-01 189-075 nGO~ erre~uneGUT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L3-01 10/20/89 PER 13,945. 13,950. 8,878.36 8,881.74 L3-01 11/29/89 APF 13,920. 14,030. 8,861.45 8,936.03 L3-01 1/18/90 APF 13,706. 13,799. 8,717.49 8,779.86 L3-01 1/18/90 APF 13,807. 13,884. 8,785.25 8,837.15 L3-01 9/25/94 SQZ 7,294. 14,030. 5,167.43 8,936.03 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE .. • L urne Oil Pool well L3-01 Technical Justification for Application for Renewal of Suspension Status September 1, 2010 Well Status Lisburne well L3-01 (PTD # 1890750) was suspended on 9/13/94 after a casing leak was identified allowing crossflow from the Cretaceous formation to the Wahoo formation. 47 bbls of 13.5 ppg class "G" cement was placed in the well from 13,903' to 12,914' on 9/15/94. slickline tagged TOC at 12,920' SLM on 9/18/94. IA x tubing communication was discovered during the pressure test to verify the cement plug. On 9/25/10 7' of perforations were shot through the tubing at 12,820' - 12,827'. 286 bbls of 14 ppg class "G" cement was pumped down the tubing, with estimated cement in the 9- 5/8" casing from 12,827' - 7,480' MD. A slickline drift on 10/7/94 tagged cement in the tubing at 12,817'. A State witnessed pressure test on the tubing to 1600 psi and on the annulus to 1420 psi passed. The 3-1/2" tubing and 9-5/8" casing were perforated from 11,680' - 11,690' on 10/23/94 and 81 bbls of 15.7 ppg class "G" cement was squeezed into the formation as well as left in the tubing. A slickline drift confirmed TOC at 7,273' on 10/25/94. A State witnessed slickline tag to 7,274' and pressure test of the tubing and the 9-5/8" casing to 1500 psi was performed on 11/7/94. The well casing is mechanically sound as proven by tubing and casing pressure tests on 11/7/94. 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 Lisburne well L3-01 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 readinas are T/I/O = 760/200/220 Well pressures were bled on 8/24/10 and are stable. Request BPXA requests approval for renewal of the existing suspension status for L3-01.' 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 be remain suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. ~ A w 4. -. TRH= McEVOY WELLHEAD = NI~EVOY ACTUATOR = AXELSON KB. ELEV = BF. ELEV = KOP= 900' Max A le = 61 8200' D9tum MD= 14065' Datum ND= 8900' SS 13-3/8" CSG, 68#, L-80, D =12.41 S' 5264 Minimum ID = 3.725' @ 13566' 4-1 /2" OTIS XN NIPPLE TOP OF CEMENT 7274' TOPOF7"LNR 13284' L 3 01 SAFETY NOTES: COMNUNICAT~N FILM ~ 9-5/8" CASING TO THE CRETACEOUS. SI~PBVDED. SEE WELL FILE 2304' OTIS SSSV HQR BV LN, D = 3.81 " nn c i iFr nnn nni~i S ST MD ND DEV TYPE VLV LATCH PORT DOTE 1 3258 2813 5 FM-10 RK 2 7108 5065 56 FMHO RK 3 10278 6760 55 FMHO RK 4 12431 7959 56 FMHO RK 5 13131 8380 54 FMiO RK 13240' I"'I 9-5/8" BAKER DB PKR ID = 4.0" 13566' 41 /7' OTIS XN NIP, ID = 3.72" 41/7'TBGIPC, 12.6#, L-80,0.0152bpf, D=3.958" 1357$' 13578' 41/7' BAKERSOS, ID=4.0" 13542' ELMD TT LOGGED 11/29/89 9-5/8" CSG, 47#, L-80, 0.0732 bpf, ID= 8.681" H 1 PERFORATION SUMMARY R~ LOG: Z-DENSfIY/CN ON 08!12189 ANGLEATTOPPB2F:48~ 13706' Ahfo~ Rafor to Rnriuc4nn fY3 fnr hic ttviral nalf [la}a SQE SPF INTERVAL OpNS z DATE 3-3/8" 6 13945-13950 O 10120/89 3-348" 2 13920-14030 O 11/29/89 3-348" 'S 13807-13884 O 01/18/90 3-3/8" *S 13706-13799 O 01/18/90 * Selected Shots I PBTD H 14320' 7"LNR, 29#, L-80, 0.0371 bpf, ID=6.184" 14368' 13935' I-{SANDANDR72FBALLS I DEFLATED BRIDGE PLUG I DATE REV BY COMMENTS DATE REV BY COMMENTS 10/24/89 ORIGINAL COMPLETION 03/04407 RL DATUM MD 11/07/94 WELL P&A'd 12109400 SIS-OAA OONVERTEDTOCANVAS 03413/01 SIS-MD FNAL 09430401 RN/TP CORRECTIONS PRUDHOEBAY UVTT WELL L3-01 P6tMT No: 89-75 AR No: 50-02 9-2 1 95 9-0 0 SEC 22 T11 N R15E BP Exploration (Alaska) ]. r-.... ~ . . f(~;".' C"':"'."~' .1" \ C-";J [r. '. ¡ ,tJ : ¡ I, \ ì ¡ !: \ ". ¡ í {\, ;, ! L, @ U L~ U lC: fí'A~\ ";:1 ¡I¡¡!L lWLr I;', n i7\ (~.J 1l r: ri:\ ;r, \ ¡ ¡ !f'd >I, ¡ y! ¡r',\, if\\ Ii f¡I,\ ",,'" !'I f!\\ ~ ~ l~j cQ) ù\\ L~ ; ì ! FRANK H. MURKOWSKI, GOVERNOR , / A 11.\ !lit IiA 0 IL AND GAS CONSERVATION COMMISSION / l 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12, 2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 1~1-D76- Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location PBU Ll PBU L2 PBU L3 Date ofSVS Test Apri123,2004 April 26, 2004 Apri127,2004 Failure Rate 30.0% 16.7% 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to \\!. th SVS test. Sincerely, 2;~ J . Norman, Chair Commissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) j . r-.... ~ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/27/2004 UnitlField1Pad: Greater Pt MclntyreILisburneIL3 Separator psi: LPS 450 HPS 450 LIP Trip ..,;> Test Test Test Date Tested and or Oil, WAG, GINJ, Code Code Code Passed Retest or SI GAS, CYCLE, SI 12/4/1993 SI OIL 81 81 81 81 81 81 81 81 81 81 81 81 81 350 350 P 6 P 1/14/2003 7/2/1994 9/9/2003 4/19/1997 12/22/1996 2/16/1997 11/17/2001 6/4/2003 6/26/1995 5/12/1997 9/7/1993 11/25/1996 7/28/2003 Wells: 1 Components: 2 Failures: 1 Failure Rate: Remarks: L3-02 4/27/2004: Grease crew notified to service S8V Page 1 of 1 SVS PBU LIS L3 04-27-04.xls ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: [] Oil [] Gas [] Plugged [] Abandoned [] Suspended [] WAG lb. Well Class: 20AAC25.105 20AAC25.110 [] Development [] Exploratory [] GINJ [] WlNJ [] WDSPL No. of Completions Zero Other [] Stratigraphic [] Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 09/13/1994 189-075 94-177 3. Address: 6. Date Spudded 13. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 07/14/1989 50-029-21959-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 08/12/1989 L3-01 287' SNL, 550' NWL, SEC. 22, TllN, R15E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: N/A RKB - 60' Prudhoe Bay Field / Lisburne Pool Total Depth: 9. Plug Back Depth (MD+TVD) 4209' NSL, 2930' WEL, SEC. 09, T11N, R15E, UM 7274 + 5157 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 707797 y- 5962008 Zone- ASP4 14375 + 9172 Ft ADL034631 TPh x- y- Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 704029 Y- 5971684 Zone- ASP4 (Nipple) 2304' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey [] Yes [] No N/A MSL 1900' (Approx.) 21. Logs Run: GR / DLL / SPECTRALOG / REL, ZDL / CNL / GR / CAL, GR / FMT, CET / CBT ! GR / CCL, GCT 22. CASING, LINER AND CEMENTING RECORD CASING · .SETTING DEPTH .. "HOLE · · ' · SIZE · :WT.:PER FT. :'GRADE :..' '..TOP.".' .... BOTTOM. SIZE... CEMENTING .RECORD: .' ' AMOUNT PULLED , 20" 91.5# H-40 Surface 115' 30" ;)150# Poleset 13-3/8" 68# K-55 / L-80 Surface 5264' 17-1/2" 3500 sx AS III, 500 sx 'G', 175 sx AS I 9-5/8" 47# K-80 Surface 13590' 12-1/4" 500 sx Class 'G' 7" 29# L-80 13304' 14368' 8-1/2" 184 sx ARC (Class 'G') 2'3. ~Perfor~t!ons OPen tO Productio.n (M.D. + TVD .of. To.p an.d.. ' 24.". ."" TUBING RECORD uottom Interval, Size and Number; iT none, state none ): ...... SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 13579' 13244' MD TVD MD TVD 251.' '.'.. i .i ;AciD, FRACTURE, CEMENT SQUEEZE, ETC. .. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12920' P&A with 47 Bbls Class 'G' 12811' 2nd Plug; 286 Bbls Class 'G' 7274' 3rd Plug; 81 Bbls Class 'G' 26. 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 FI0wTubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE'-~ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate: sheet, if neceSsary). Submit core chips; if none, state "none". ,,' n lr, iNAI Form 10-407 R~,~~..,~..~ SEP 5, 20,03 CONTINUED ON REvI"RSE SIDE 28. GEOLOGIC MARKEF~'~ 29. ~ ~ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Wahoo Zone 7 13687' 8705' None Wahoo Zone 6 13812' 8789' Wahoo Zone 5 13997' 8914' Wahoo Zone 4 14120' 8997' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble/'~/~_~, Title TechnicalAssistant Date L3-01 189-075 94-177 Prepared By Narne/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer' (~ENERAL: ITEM la: ITEM 4b: ITEM 8; ITEM '13: ITEM 20: ITEM 22: ITEM 23: ITEM 26: ITEM 27: INSTRUCTIONS This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean Iow Iow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The APl number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). True vertical thickness. Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ORIGINAL AOGCC L3-01 P &A PAGE {~' P. 02 Summary of Events 5294 Pressure test 13 3/8" annulus to 2000 psi with $ bbls diesel. Held solid for 15 minutes. 06-05~94 CTU scale cleanout. CTU operations included 1 3/4" coil, a 2 1/8" Drlllex motor and a 2,75" diamond mill bit. The coit was run in hole at 2 FPM pumping 2 BPM $1i=k seawater, Minimal scale was observed during the entire job. BHA was run in hole without tagging to 1,3,900' MD. Previous 'tag depth on 6-16-90 was at 13,938' MD. 08-21.94 Completed dummy gun tag for P&A. Hit obstruction at 1410' MD. 08-25-94 Tag ice at 1405' MD, 08-30-94 09-06-94 09-10-94 Jet ice plug from 14S0' to 88S0' MD. Freeze protect to 6000' MD, ' Shot circulating hole8 in tubing above and below packer. Perforation depths below packer at 13,274-284' MO and above packer e,t 13,220-230' MD. Used 1 11/16" hollow carrier tubing punch guns loaded with 4 SPF. Pulled live gas lift valve from 7108' MD and ran dummy valve, 09-12-94 Establish injeotivity with MEOH/weter at 4,0 BPM and 220 psi, Pumped 2500# (1250# 20140 mesh and 1250# 100 mesh) sand into Wah(3o Zones 7 and 6. Estimated sand top at 13838' MD, 09-12-94 T~..g sand top with slicklir~e. Tag at 13,903' MD corrected to tubing tall. 09-13-94 RU CTU. 8tart pumping seawater down 9 5/8" annulus. Pump 400 bbls at 2 BPM. RIH with coil tubing, Tag PBTD st 13,903' MD. Begin circulating sewater down coil at 2_ BPM, Pumped 546 bbls down backside and switched to MEOH/wa, ter, Pumped :39 bbls 40160 for freeze protect. Start pumping freshwater down coil. At 10 bbls away switched to 13.5 ppg ciasa 'G' cement, Parked ocli at 13,903' and after 3 bble out nozzle pick up hole laying in cement. Laid in 47 bb~s of 13.5 ppg class 'G' cement from 1 to 12,914' MD (expected TOG). Bottom mandrel located at 13,131' MD. WOC 5 days, 09-18-94 Tag cement with 3.5" centralizer at 12,920' SLMD. Surfa¢e tubing pressure at this time was ;250 psi and the tubing was liquid paci~ed which indicated the Wahoo was 'not communicating with the surface, Attempt to increase surface pressure to 1500 psi per. REEEIVED JAN 1 '~ 1995 oi~ & Gas Oon$. Oornmi~ion 0?'; AOGCC PAGE P. 4,,'6 State inspectors request. After pumping 10 BBL$ of diesel minimal pressure increase was noted. The well remained liquid packed so it did not appear the cement plug .w.a$ leaking (the Wahoo pressure is unable to support the liquid column in the well), The estimated pressure st the plug wa,s approximately 4000 psi based on fluids pumped. This is a minimum of 900 psi over expected reservoir pressure in this area. The plug was m-tagged and had not moved down. Since tubing by annulus communication was suspected a larger pump was called out and liquid levels were shot in the annulus. The tubing remained liquici packed. With 1500 psi on the annulus the liquid level was at 3350' MD, The pump truck was rigged up and beg~n pumping diesel at 3 BPM. The wellhead pressure increased from 250 to 650 psi. Rate was decreased until a stabilized leak rate of 0.25 BPM w~s observed at 875 psi WHP, Annulus pressure increased to 1700 psi after having pumped approximately 32 BBLS of diesel. A liquid level was shot at this point and the level rise in the annulus was calcu[ated at 580' MD, which is equiv,slent to a 31 BBL increase which proved the tubing was communicating to the annulus, 03 Note; Per ~ommun[~ation between George Phillips and Blair Wondzell on 09-21-94'it was agreed the leak did not e[ppear to be to the Llsburne and Mr. Wondzel[ gave verbal approval to proceed with the P&A. 09-P-5-g4 Note: 09-30-94 Ran a leak detection Icg on L3-01 with sptnner/press/temp tools. The initial pressure on the tubing was 450 psi, The initial pressure on the annulus was 1550 psi and liquid level wac approximately 3300' MD. The spinner/pressure/tamp tool was run to 12,900' MD and then crude was started down the tubing, Tubing pressure started coming up after less than 10 BBL were Indicating a full column of liquid in the tubing. Injection rate was stabilized at 0.5 BPM, The stop count at 12,900' MD was 2.4 rev/sec, The tools were logged at 150 fpm. There were no indications of leaks anywhere In the tublng~ P&A operation continued with perforating through tubing from 12,820' to 12,827' MD using 1 11!16" hollow carrier tubing punch gun loaded with 4 SPF. On 9/28 George Phillips talked to Dave Johnson about the necessity of leading end following the cement in the second phase of the procedure with a heavy brine. The extra hydrostatic heed could result in incressed fluid lOss to the Cretaceous. Mr, Johnson gave verbal approval to use a lighter fluid. Pumped 286 bbls of 14 ppg Class 'G' cement down tubing followed by 155 bbls seawater and 45 bbls MEOH/Water for freeze protect. Estimated cement in 9 5/8" casing from 12,827' to 7,480' MD. RECEIVED ,JAN 1 7 1995 Alaska Oil & Gas I~0n~. Comml~sto~ ~ndhnr~ -~ · I0-07.-94 AOGCC PAGE 04 ( P. 5/'6 Sltckline tagged cement top In tubing at 12,817' MD. State witnessed pressure test tubing to 1600 psi and 9 5/8" annulus to 1420 psi. 10-0g-94 An attempt was made to run a cement bond Icg in the $1/2" tubing string. Due to problems with centralization of the tubing string the icg quality was suspeot, Tool stuck in collar at 7561' MD, Pulled tool free but lost Gemco centralizer in tubing. 10-10-94 Pushed centralizer downhole and drifted tubing to 12,400' MD. 1 O- 11-94 Perforated through 3 1/2" tubing and 9 5/8" casing from 11,680' to 11,690' MD with 8 3/8" hollow carrier gun loaded at 6 SPF, These perforations are between the Cretaceous and the 8adlerochit formations. 10,,23-94 RU CTU. Perform inJectivlty test while running in ho[e, 3-4 gpm at 1,500 psi. Ta~gg~e_d PBTD at 12,81.1' MD and PUH to 11,700' MD. Start pumping 15% HCL to break down' perforations and oement behind the 9 5/8" annulus, Pumped 5 bbls acid and switched to seawater. Pumped 20 bbls seawater and switoh to MEOH/water. Acid at nozzle, PUH to 11,670' MD and ~hut-in backside to squeeze acid away into peffs, Wi[h 21 bbls away the injectivity was limited to 0.1 bpm ~t 1580 psi. RIH with coil to 12,811' MD and start pumping seawater. Switch to 15.7 ppg claes 'G' after lO bbla away. After cement reaohed nozzle began PUH while laying in oement. Pumped 81 bbls oement and switched to 60/40 MEOH/water for freeze protect. Expected top of eement at 7,500' MD, 10-P-5-94 Sllckline tagged cement at 7,273' MD. 11-07-94 Sl[~kline tagged cement top in tubing at 7,274' MD. State witnessed pressure test tubing to 1500 psi and 9 5/8" annulus to 1500 psi. Bled tubing and annulus to 500 psi. L3-01 Remaining Work Attachment 1 Is a schemati¢ of the current status of Lisbume well L3-01, Alt cementing operations have been completed on the well The following lists the remaining procedural steps required for fine[ P&A as outlined in the originai Application for Sundry Approvals dated and signed on 07-07-94, It is requested these remaining steps be deferred until final pad abandonment. 1) Have AOGCC witness that the' 13 3/8" will pressure test to 2000 psi. Obtain waiver for additional cementation, Please see Note below, RECEIVED JAN I 7 1995 Alaska Oit & Gas Cons. Commissto~ Anchora '." 08/14/2003 · 10' 44 9872767542 AOGCC PAGE 2) Cut 4 1/2" tubing at 16.~ ft or greater betow the ground level, i.e. P-05' MD. 3) Remove cut 4 1/2" tubihg using crone. 4) 5) Make junk bailer run down to 230' MD. Run 9 5/8" ClBP down to 165' or more below grade elevation, i,e. 205' MD. AOGCC witness to be on location for verifying plag location. Rig up dry hole tree, RU E.line and perforate 9 518' casing st 200' MD with 4 1/2" casing guns Ibaded at 6 shots with 60° phasing, Establish circulation down 9 5/8"' and out the 13 3t8" annulus. Circulate oement out the annulus leaving a Cement plug inside and outside the 9 5/8" from 205' MD to surface, Arcticset I @ 15.7 ppg to be used. Note: This procedure step deviates from the original Sundry application which was to dump cement on top of the bridge plug. Since the 13 3/8" annulus is not Arc, tie jpacked the above method will leave a signifioant quantity of cement ~n this annulus ancl guarantee a competent plug in the 9 5/8", 6) 7) Remove dry hole tree. Dig out around cellar to 5' below ground level, Cut off all casing strings at least 3' below~ground level. The gravel pad should be 5' thick~ ~t,~ ,,~' Weld steel plate on top of oasing strings with the following information per 20 AAC 25.120 6 d. This procedure must be witnessed by AOGCC. ARCO,'Ala~ka, Inc. Prudhoe Bay Unit Llsbume Well L3-01 287' FML, 550' FWL, Sec. 22, T11N, R15E, UM Back fill the excave,tion. Submit a report of all activities to GPMA Operations Engineering so all necessary notices may be filed with the AOGCC. 05 RECEIVED JAN 1 ? 1995 Oil & Gas Cons. Comml~sio~ Anchora 'r' 08/14/2003 ia:44 9072767542 ( AOGCC PAGE 01 Calculations Char ' IVED ................. JAN 1 7 199,5 ....... Oil & ~as Co~. Co~iml~lo6 ' Anchora.i;~ ., ARCO ALASKA, INC. 700 "G" ST. ANCHORAGE. AK 99501 GREATER POINT McINTYRE FACSIMILE TRANSMISSION MACHINE (907) 2~34894 VERIFY (907) 263-4382 DATE: I /[~ /~,.~- NUMBER OF PAGE$: C + fi' TO; COMPANY: LOCATION: FROM: PHONE #: COMMENTS: ii RECEIVED dAN ] 7 1995 Ataska Oil & Gas Cons. Commission Anchora , 3AH l? '95 07:54AH .... ARCO Subject Fii~ .... number Calculations Cha ........ IVED ..... .,. ~ ~~-~~-~ o~, ~ 1~ ........ Alaska 0il & Gas Cons. Commissioi~' ... /tnchora ~ , , ,~ 05-15..-94 06-05-94 08-21-94 08-25-94 08-30-94 09-06-94 09-10-94 09-12-94 09-12-94 09-13-94 09-18-94 L3-01 P & A Summary of Events Pressure test 13 3/8" annulus to 2000 psi with 5 bbls diesel. Held solid for 15 minutes. CTU scale cleanout. CTU operations included 1 3/4" coil, a 2 1/8" Driilex motor and a 2,75" diamond mill bit. The coil was run in hole at 2 FPM pumping 2 BPM slick seawater, Minimal scale was observed during the entire job. BHA was run in hole without tagging to 13,900' MD. Previous tag depth on 6-16-90 was at 13,938' MD. Completed dummy gun tag for P&A. Hit obstruction at 1410' MD. Tag ice at 1405' MD. Jet ice plug from 1450' to 3350' MD. Freeze protect to 6000' MD, Shot circulating holes in tubing above and below packer. Perforation depths below packer at 13,274-284' MD and above packer at 13,220-230' MD, Used 1 11/16" hollow carrier tubing punch guns loaded with 4 SPF. Pulled live gas lift valve from 7108' MD and ran dummy valve, Establish injectivity with MEOH/water at 4.0 BPM and 220 psi. Pumped 2500# (1250# 20/40 mesh and 1250# 100 mesh) sand into Wahoo Zones 7 and 6, Estimated sand top at 13838' MD, Tag sand top with slickline. Tag at 13,903' MD corrected to tubing tail. RU CTU. Start pumping seawater down 9 5/8" annulus. Pump 400 bbls at 2 BPM. RIH with coil tubing, Tag PBTD at 13,903' MD. Begin circulating sewater down coil at 2 BPM. Pumped 546 bbls down backside and switched to MEOH/water. Pumped 39 bbls 40/60 for freeze protect. Start pumping freshwater down coil. At 10 bbls away switched to 13.5 ppg class 'G' cement. Parked coil at 13,903' and after 3 bbls out nozzle pick up hole laying in cement. Laid in 47 bbls of 13.5 ppg class 'G' cement from 13,903' to 12,914' MD (expected TOC). Bottom mandrel located at 13,131' MD. WOC 5 days, Tag cement with 3.5" centralizer at 12,920' SLMD, Surface tubing pressure at this time was 250 psi and the tubing was liquid packed which indicated the Wahoo was 'not communicating with the surface, Attempt to increase surface pressure to 1500 psi per RECEIVED JAN 1 7 1995 0il & Gas Cons. Commission An~.hnrn ~ Note; 09-25-94 Note: 09-30-94 State inspectors request. After pumping 10 BBLS of diesel minimal pressure increase was noted, The well remained liquid packed so it did not appear the cement plug was leaking (the Wahoo pressure is unable to support the liquid column in the well), The estimated pressure at the plug was approximately 4000 psi based on fluids pumped. This is a minimum of 900 psi over expected reservoir pressure in this area. The plug was re-tagged and had not moved down, Since tubing by annulus communication was suspected a larger pump was called out and liquid levels were shot in the annulus. The tubing remained liquid packed. With 1500 psi on the annulus the liquid level was at 3350' MD, The pump truck was rigged up and began pumping diesel at 3 BPM. The wellhead pressure increased from 2,50' to 650 psi. Rate was decreased until a stabilized leak rate of 0.25 BPM was observed at 875 psi WHP. Annulus pressure increased to 1700 psi after having pumped approximately 32 BBLS of diesel. A liquid level was shot at this point and the level rise in the annulus was calculated at 580' MD, which is equivalent to a 31 BBL increase which proved the tubing was communicating to the annulus, Per communication between George Phillips and Blair Wondzell on 09-21-94 it was agreed the leak did not appear to be to the Lisburne and Mr. Wondzell gave verbal approval to proceed with the P&A. Ran a leak detection log on L3-01 with spinnedpress/temp tools. The initial pressure on the tubing was 4,50 psi, The initial pressure on the annulus was 1550 psi and liquid level was approximately 3300' MD. The spinner/pressure/temp tool was run to 12,900' MD and then crude was started down the tubing, Tubing pressure started coming up after less than 10 BBL were indicating a full column of liquid in the tubing, Injection rate was stabilized at 0.5 BPM, The stop count at 12,900' MD was 2.4 rev/sec. The tools were logged at 150 fpm. There were no indications of leaks anywhere in the tubing. P&A operation continued with perforating through tubing from 12,820' to 12,827' MD using 1 11/16" hollow carrier tubing punch gun loaded with 4 SPF, On 9/28 George Phillips talked to Dave johnson about the necessity of leading and following the cement in the second phase of the procedure with a heavy brine. The extra hydrostatic head could result in increased fluid loss to the Cretaceous. Mr. Johnson gave verbal approval to use a lighter fluid. Pumped 286 bbls of 14 ppg class 'G' cement down tubing followed by 1,55 bbls seawater and 45 bbls MEOH/water for freeze protect. Estimated cement in 9 5/8" casing from 12,827' to 7,480' MD. RECEIVED JAN 1 ? 1995 Alaska 0ii & Gas Cons. Commission Anchora ~ JHM 1F '~b I~IF;3OHP1 m.ozo 10-07-94 Slickline tagged cement top in tubing at 12,817' MD, State . witnessed pressure test tubing to 1600 psi and 9 5/8" annulus to >%,,~ '~' 1420 psi. 10-09-94 An attempt was made to run a cement bond Icg in the 3 1/2" tubing string, Due to problems with centralization of the tubing string the log quality was suspect, Tool stuck in collar at 7561' MD. Pulled tool free but lost Gemco centralizer in tubing. 10-10-94 Pushed centralizer downhole and drifted tubing to 12,400' MD, 10-11-94 Perforated through 3 1/2" tubing and 9 5/8" casing from 11,680' to 11,690' MD with 3 3/8" hollow carrier gun loaded at 6 SPF, These perforations are between the Cretaceous and the Sadlerochit formations. 10-23.,-94 RU CTU. Perform injectivity test while running in hole, 3-4 gpm at 1500 psi. T~agged PBTD at 12,811' MD and PUH to 11,700' MD. Start pumping 15% HCL to break doWn- perforations and cement behind the 9 5/8" annulus, Pumped 5 bbls acid and switched to seawater. Pumped 20 bbls seawater and switch to MEOH/water. Acid at nozzle, PUH to 11,670' MD and shut-in backside to squeeze acid away into parrs, With 21 bbls away the injectivity was limited to 0.I bpm at 1530 psi. RIH with coil to 12,811' MD and start pumping seawater. Switch to 15.7 ppg class 'G' after 10 bbls away. After cement reached nozzle began PUH while laying in cement. Pumped 81 bbls cement and switched to 60/40 MEOH/water for freeze protect. Expected top of cement at 7,500' MD. 10-25-94 Slickline tagged cement at 7,273' MD, 11-07-94 Slickline tagged cement top in tubing at 7,274' MD. State witnessed pressure test tubing to 1500 psi and 9 5/8" annulus to 1500 psi. Bled tubing and annulus to 500 psi. L3-01 Remaining Work Attachment 1 is a schematic of the current status of Lisburne well L3-01. Ail cementing operations have been completed on the well. The following lists the remaining procedural steps required for final P&A as outlined in the original Application for Sundry Approvals dated and signed on 07-07-94, It is requested these remaining steps be deferred until final pad abandonment. 1) Have AOGCC witness that the 13 3/8" will pressure test to 2000 psi. Obtain waiver for additional cementation, Please see Note below. RECEIVED JAN 1 '7 1995 Alaska .0il & Gas Cons. Commission Anch0ra JAM 17 ~5 O~F:~G~M ~.~ 2) 3) 4) s) 6) 7) 8) Cut 4 1/2" tubing at 165 ft or greater below the ground level, i.e. 205' MD. Remove cut 4 1/2" tubing using crane, Make junk bailer run down to 230' MD. Run 9 5/8" CIBP down to 18,5' or more below grade elevation, i,e, 205' MD. AOGCC witness to be on location for verifying plug location, Rig up dry hole tree, RU E-line and perforate 9 5/8" casing at 200' MD with 4 1/2" casing guns loaded at 6 shots with 60° phasing, Establish circulation down 9 5/8" and out the 13 3/8" annulus, Circulate cement out the annulus leaving a cement plug inside and outside the 9 5/8" from 205' MD to surface. Arcticset I @ 15,7 ppg to be used. Note: This procedure step deviates from the original Sundry application which was to dump cement on top of the bridge plug, Since the 13 ,3/8" annulus is not Arctic packed the above method will leave a significant quantity of cement in this annulus and guarantee a competent plug in the 9 5/8", Remove dry hole tree. Dig out around cellar to 5' below ground level, Cut off all casing strings at least 3' belowL)ground level. The gravel pad should be 5' thick. ~.,.?,,,,~ Weld steel plate on top of casing strings with the following information per 20 AAC 25.120 6 d. This procedure must be witnessed by AOGCC. ARCO, Alaska, Inc. Prudhoe Bay Unit Lisburne Well L3-01 287' FNL, 550' FWL, Sec. 22, T11N, R15E, UM Back fill the excavation. Submit a report of all activities to GPMA Operations Engineering so all necessary notices may be filed with the AOGCC. RECEIVED JAN ~ ? 1995 Oil & Gas Cons. C0mmissio~ Anchom ~ ARCO Alaska Inc. Greater Point McIntyre Engineering Date: November 23, 1994 Subject: Transmittal Number 749 .~ From: ARCO Alaska, Inc. To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Greater Point MclntYre Area data are enclosed. Tl~l~formation and your cooperation in maintaining confidentiality is appreciated: Well Name Data Description Run # eak Detection Log, 1 PIN/TEMP/PRESS/GRADIO , L3-01 Tubing Puncher Record ( 1 n/~s. Tubing 1 Puncher) erforation Record (3 3/8" HSD- 4lB HJ II 6 spf) 1 ~ement Bond Log (CBTE/SGTL/CALY) 1 Diskette: CDR in LDWG format ~ 1 ~~rforating necord.~. (3 3/8"-20'- 6spf)~~}~'~ ,;~'1 ~ g Record (3 /8 HSD- 4lB HJII) ~ .~~erf°ratinl CDN in LDWG format (w/listing) ~~LWD Dep th Corrected) 1 ~/5~~~~~ 5 Pass Cased Hole TDTP ~ Diskette: 5 (w/listing) Date Run 9/25/94 9/25/94 10/8/94 10/8/94 6/16/94 ,q 9/])194 10/9/94 11/2/94 6/13/94 6/14/94 1/9/94 is confidential Company Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Transmittal Number: 749 Page: I MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David John~_...~~, Chairmar~ Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi,~ SUBJECT: Petroleum Inspector DATE: October 7, 1994 FILE NO: PD9JJGBD.DOC Perforations Plug verification Arco well # L3-01 ,~ Lisburne Field PTD #89-75 Sunday, September 18, 1994: I traveled to Arco's drill site L-3 to witness the verification of placement of the cement plug at perforations in well #01. Jim Moore (Arco rep.) was in attendance. The plug which conSisted of 47 bbl's of class "G' cement had been laid on the previous week with coil tubing at 13903 (CTM). A slick line unit was used to run a tubing tail locater with a sample bailer below it. The end of tubing was found to have cement up into it and the top of cement was tagged at 12,920 (WLM) with the top of perf's at 13,706 (ELM). This left a 786' (approximately) plug over the top perf. A pressure test to 1500 psi was attempted but the tubing would not pressure up. Ten barrels were put away with no success, the plug was then tagged again at 12,920' (WLM). Chris Alonzo and Jim Moore (AAI rep.) will investigate and report to AOGCC on the cause of the failed pressure test. ,Friday, October 7, 1994; I returned to this location to witness the retest of the perforations plug. Steve Wysocki (AAI rep.) informed me that the tubing had been perforated at 12820 (ELM) and 286 bbl's of cement had been circulated down the tubing and up the 9 5/8 casing in a attempt to close off the communication with the Cretaceous. The tubing was displaced with water. A tag with wireline found TOC at 12,817 (WLM) and a 1600 psi pressure test was performed on the tubing. I requested a pressure test on the annulus and 1500 psi was applied to the 9 518. Both pressure tests were successful. SUMMARY: I witnessed the verification of placement of the cement plug at perforations in Arco's well L3-01. Attachments: PD9JJGBD.XLS STATE OF ALASKA ALASJ~t OIL AND GAS CONSER VA TION COMMISSION Plug And Abandonment Report Operator: Arco Alaska Inc. Operator Rep.: Jim Moore Lease No.: Well No.: Total Depth: Well Name: L3-01 PTD No.: 89-75 Sec. T-R S22, T11N, R15E. 14368 Elevation: Date: 9/18/94 Meridian: Umiat Mud Wt.: ppg. CASING DATA: Drive Pipe: O.D." Set@: ft. With Penetration Conductor: O.D." Set @: ft. Surface: O.D." Set @: Intermediate: O.D." Set @: ft. Prodctn: O.D." Set @: PLUGGING DATA: 1. Open Hole Plugs: 2. Open Hole Isolation Plugs: 3. Perforation Plugs: Laid plug (9-13-94) wi ctu 47 bbl's class "g" ~ 13903. Tagged plug at 12920 (WLM) Plug Failed 1500 psi pressure test. Retagged plug at 12920' (WLM) 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet REMARKS: Plug tag "OK" but could not gain pressure during test, Jim Moore (AAI rep) will investigate. 10/7/1994; Returned to pressure test after tubing was perfed @12820and 286 bbl's cement circulated down tubing and up 9 5/8" casing. Tag cement w\ wireline at 12,817 (WLM THF). pressure test tubing to 1600 psi "OK". Pressure test 9 5/8 to 1550 psi "OK" Distribution: orig - Well File c - Operator c- DNR/DOG c- Database c - Rpt File c- Inspector Inspector (s): Louis R Grimaldi FI-000 (Rev. 3/93) PD9JJGBD.XLS ARCO Alaska Inc. Greater Point McIntyre Engineering Date: Subject: From: September 29, 1994 Transmittal Number ARCO Alaska, Inc. 745 To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Greater Point Mclntyre Area data are enclosed. and your cooperation in maintaining confidentiality is appreciated: Well Name Data Description L3-01 ...~Tubing Puncher Record ~' .!~.J~'/'x~ RAB-Final ~L) ~f ~--~Bit and Ring Resistivity ~ ~DR-Final ~ L~ C~R-Very Enhanced Resistivity-Gamma Ray ~, ~rue Vertical Depth CDR-Final ~njection Profile Log (Press-Temp-SPIN-GR) i~ ~nectl0nProfll Lo Pr ssT m PIN ~1 j ' 'e g( e - e p-S -GR) ~06 Perforation Record 2-1/~'' Phased EJIII 6 SPF ~-07 Perforating Record with GR/CCL Jewelry Log ~ Perfo~apon Record 3-~/d' HSD 4lB HJII 6 SPF ~2-1p/ perforating Record with GR/CCL Jewelry Log ~2-18 Static Pressure Survey-Press-Temp ~2-21 Perforation Record 3-3/8" HSD 4lB HJII 6 SPF Transmittal Number: 745 Page: This in ~o ~°~m~a~'io~~7~J!~n fi d e n t i a 1 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger I 8/23/94 Schlumberger 1 8/23/94 Schlumberger I 7/27/94 Schlumberger 1 7/27/94 Schlumberger I 7/21/94 Schlumberger 1 7/25/94 Schlumberger I 7/25/94 Schlumberger I 7/22/94 Schlumberger 1-12 3/6/94 Schl. umberger Run # Date Run Company I 9/6/94 Schlumberger MEMORANDUM TO: THRU' State of Alaska Alaska Oil and Gas Conservation Commission David J o h_..~.[l~n,'"~"' Chairm~.~.~ Blair. Wondzell, ~?~ P. I. Supervisor 9[~fi/~ FROM' Lou Grima~(~i, ~ SUBJECT: Petroleum Inspector DATE: September 18, 1994 ., FILE NO: PD9JIQBD. DOC Perforations Plug verification Arco well # L3-01 Lisburne Field PTD #89-75 Sunday~ September !8, 1994: I traveled to Arco's drill site L-3 to witness the verification of placement of the cement plug at perforations in well #01. Jim Moore (Arco rep.) was in attendance. The plug which consisted of 47 bbl's of class "G" cement had been laid on the previous week with coil tubing at 13903 (CTM). A slick line unit was used to run a tubing tail locater with a sample bailer below it. The end of tubing was found to have cement up into it and the top of cement was tagged at 12,920 (WLM) with the top of perf's at 13,706 (ELM). This left a 786' (approximately) plug over the top perf. A pressure test to 1500 psi was attempted but the tubing would not pressure up. Ten barrels were put away with no success, the plug was then tagged again at ~,~ 12,920' (WLM). ,~^,~,~ Chris Alonzo and Jim Moore (AAI rep.) will investigate and report to AOGCC on the cause of the failed pressure test. SUM..MARY: I witnessed the attempted verification of placement of the cement plug at perforations in Arco's well L3-01. Attachments: PD9JIQBD.XLS ALASKA OIL AND GAS CONSER VA TION COMMISSION Plug And Abandonment Report Operator: Arco Alaska Inc. Operator Rep.: Jim Moore Lease No.: Well No.: Total Depth: Well Name: L3-01 PTD No.: 89-75 Sec. T-R S22, TllN, R15E. 14368 Elevation: Date: Meridian: Umiat Mud Wt.: CASING DATA: Drive Pipe: O.D." Set @: ft. With Conductor: O.D." Set @: ft. Surface: O.D." Set @: Intermediate: O.D." Set @: ft. Prodctn: O.D." Set @: PLUGGING DATA: 1. Open Hole Plugs: 9/18/94 PPg. Penetration 2. Open Hole Isolation Plugs: 3. Perforation Plugs: Laid plug (9-13-94) w/ctu 47 bbl's class "g" (~ 13903. Tagged plug at 12920 (WLMI plu~l Failed 1500 psi pressure test. Reta~]ed plu~l at 12920' (WLM) 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet REMARKS: ,plu~l ta~l "OK" but could not ~lain pressure durin~l test, Jim Moore (AAI rep) will investigate. Distribution: orig - Well File c - Operator c- DNPJDOG c - Database c- Rpt File c- Inspector FI-000 (Rev. 3/93) Inspector (s) · Louis R Grimaldi PD9JIQBD.XLS ARCO' Alaska, inc. Post office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 30, 1994 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Road Anchorage, AK 99501-3192 Re: Lisburne Well L3-1 Abandonment Sundry Dear Mr. Johnston: ARCO Alaska, Inc., as Operator of Lisburne Participating Area, requests Sundry Approval for the abandonment of Well L3-1. A casing leak has been identified in Well L3-1 which is believed to be allowing crossflow from the Cretaceous formation to the Wahoo formation. Scale deposits in the tubing and gaslift equipment prevent the setting of any plugs to eliminate this crossflow. Extensive reservoir studies have failed to provide the required economic justification to restore the mechanical integrity and resume production. A review of possible abandonment operations has led us to propose the attached procedure as one that should satisfy all safety and environmental concerns. While somewhat unorthodox in nature (e.g., leaving the tubing in-place), we feel that this is the most cost effective procedure to meet regulatory requirements. In order to minimize the amount of fluid crossflow, abandonment operations will commence upon Commission approval. If you have any questions or desire additional information, do not hesitate to call me at 265-6538. Sincerely, .. ) , Engineering Supervisor Lisburne/Point Mclntyre Engineering JLH/jm Attachment ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon ~ Suspended __ Operation Shutdown Alter casing __ Repair well __ Plugging x than ram __ Pull tubin~_ Variance_ 2. Name of Operator 15. Type of Well: ARCO Alaska, Inc. | Development ~ ! Exploratory __ 3. Address | Stratigraphic __ P.O. Box 100360, Anchorage, AK 99510 ! Service __ __ Re-enter suspended well __ Time extension__ Stimulate Perforate Other 6. Datum elevation (DF or KB) RKB=35' 7. Unit or Property name Lisburne Location of well at surface 287' FNL, 550' FWL, Sec.22, T11N, R15E, UM At top of production interval 1553' FNL, 2482' FWL, Sec.9, T11N, R15E, UM At effective depth 1106' FNL, 2341' FWL, Sec.9, T11 N, R15E, UM At total depth 1072' FNL, 2331' FWL, Sec.9, T11 N, R15E, UM 8. Well number L3-01 9. Permit number 89-75 10. APl number 500292195900 11. Field/Pool Prudhoe Bay / Lisburne 12. Present well condition summary Total Depth: measured: true vertical: 14375 feet Plugs 91 72 feet measured) Bridge Plug @ 13938' MD Effective Depth: Casing Conductor Surface Intermediate measured: true vertical: Length 80' 5229' 13555' Size 20" 13 3/8" ,5/" 14326 feet Junk (measured) GLV @ 14326' MD 9138 feet Cemented Measured depth True vertical depth 2150#Poleset 115' 115' 3500 sx ASlIi& 500 sx 5264' 3993' Class "G"-Topjob w/175 500 sx SSII 13590' 8640' Liner 1 064' 7" 184 sx ARC (Class G) 13304-14368' 8462-9167' Perforation depth: measured 13706-14030' true vertical 8718-8936' (note: 13945-13950 squeezed perfs, bridge plug covers 13938-14030 ) R[CEIVED Tubing (size, grade, and measured depth) 4 V2, L-80, tbg w/tail @ 13579' Packers and SSSV (type and measUred depth) Baker 'DB' pkr @ 13244', HRQ' SSSV @ 2304' 13. Attachments Description summary of proposal x~ Detailed operation program __ ,JUL. -'1 t994 ".. ~;.' :;~.~. !)ii & Gas 00ns. BOP sketch ---- Jof) 14. Estimated date for commencing operation I15. Status of well classification as: August 1, 1994 I Oil X Gas Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ined Glenda S.~~~ n ~:~ ~,.~~,'1.. Title Sr. Enqineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~ ~(~ ~ ¢¢~, ¢~.1L ~-J~-I ApprovaI No. Plug integrity ~ BOP test Location clearance ~ ~'~"- / ~ "7 Mechanical.Integrity Test Subsequent for required 10- / Si ned By Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE CURRENT CONDITION WELL L3-01 SCHEMATIC APl # 50-029-21959 ~3 13 11 O~~12 16 Well Status: Producer Surface Location: 287 FNL, 550 FWL, Sec 22, T11N, R15E, UM Top Lisburne Loc:1553 FNL, 2482 FWL, Sec 9, T11N, R15E, UM RKB To Tubing Hanger: 35 Feet Top of Wahoo: 13687 MD/8643 SS Datum: 14067 MD/ 8900 SS Reference Log: Z~Density/CN(Porosity), 08/12/89 Annulus Fluid: 8.5 ppg Sea Water below 7108' MD. Spud Date: 7-14-89 Completion: 12-04-89 NOTE: Leak from the 9-5/8" casing to the Cretaceous. . 2. 3. 4. 35 MD -- 4-1/2" TBG HANGER, 4-1/2" X 12.6#, L-80, IPC 2304 MD--OTIS SSSV 'HRQ' BVLN, 3.813"1D - WIRELINE RETRIEVABLE 5264 MD--13-3/8" x 68#, L-80 CSG. SET GAS LIFT MANDRELS DEPTH MANDREL TYPE VALVE LATCH 3256 MD McMURRY 1-1/2"FMHO DUMMY RK 7108 MD McMURRY 1-1/2"FMHO 1/4" port RK 10278 MD McMURRY 1-1/2"FMHO DUMMY RK 12431 MD McMURRY 1-1/2"FMHO DUMMY RK 13131 MD McMURRY 1-1/2" FMHO5/16"ORF. RK 6 ":~ :.7 ~ .:. ;:::~ 6. 13244 MD - BAKER 'DB' PACKER, 7. 13304 MD - TOP OF 7" X 29# L-80 LINER 7 8. 13532 ELMD - OTIS 'XN' NIPPLE, 3.725"1D 10 TRO 2570 SS DEPTH (2753 SS) (5oo4 ss) (6699 SS) (7899 SS) (83oo ss) 5. 13005 MD - Top of BaSO4 scale, on 12/19/93 Wireline was able to get a 3.81" gauge ring to 13005' MD, a 2" sample bailer to 13074' MD and a 1.75" toolstring to 13083' MD. 9. 13543 ELMD - BAKER SHEAR OUT SUB/TT, 4.0"ID 10. 13590 MD - 9-5/8" x 47# L-80 CASING 11. WAHOO 7 PERFS 3-3/8" TT 0° PHASE (8656-8725' SS) 13706, 12, 17, 26, 34, 45, 50, 58, 64, 72, 85, 91, 95, 99 13807 12. WAHOO 6 PERFS 3-3/8" TT 0° PHASE (8732-8854' SS) 13817, 22, 34, 82, 84 13920- 13997 2JSPF 180° 13. 13938' MD - PBTD (6-16-90). FILL CONSISTS OF SAND/BALLS ON TOP OF BRIDGE PLUG. 14. WAHOO 5 PERFS 2 JSPF 180° (8854-8875' SS) 13997- 14030 MD 15. SQUEEZE PERFS 6 SPF 13945-13950 16. WAHOO 4 -NOT PERFORATED 17. FISH -- 1-1/2" McMURRY ORF. GLV w/ RK LATCH. LOST 2/20/90. 18. 14375 MD-- TD HOLE ANGLE THRU WAHOO' 47 DEGREES MAXIMUM HOLE ANGLE' 62 DEGREES @ 8500 MD Max. H2S Measured = 60 PPM (ON GAS LIFT) - CALCULATED = 160 PPM (FORM GAS ) RECEIVED , ", & Gas C,,)r~s. C0rrim/ssior~ IWELL L3-01 SCHEMATIC APl # 50-029-21959 PLUGGED CONDITION Well Status: Producer Pad Level: 5' Spud Date: 7-14-89 Completion: 12-04-89 ,{ lo{ 22 12 14 18 19 21 23 17 1. TOP of 9-5/8" CASING, (BOTTOM OF CEMENT PLUG 205', 15.7# ARCTICSET III) MECHANICAL BRIDGE PLUG AT BASE 2. 4-1/2" X 12.6#, L-80, IPC 3. 205-7500 MD-- BRINE MINIMUM WT. 10.3 PPG BETWEEN SURFACE PLUG AND ANNULUS TUBING PLUG 4. 2304 MD-- SSSV REMOVED. 5. 5264 MD--13-3/8" x 68#, L-80 CSG. SET. CASING TESTED ON MAY 15, 1994. HELD 2000 PSI FOR 15 MINUTES 6. GAS LIFT MANDRELS DEPTH MANDREL TYPE VALVE 3256 MD McMURRY 1-1/2"FMHO DUMMY 7108 MD McMURRY 1-1/2"FMHO DUMMY 10278 MD McMURRY 1-1/2"FMHO DUMMY 12431 MD McMURRY 1-1/2"FMHO DUMMY 13131 MD McMURRY 1-1/2" FMHO 5/16" ORF. 7. 8300-10400 MD CRETACEOUS LATCH SS DEPTH RK (2753 SS) RK (5004 SS) RK (6699 SS) RK (7899 SS) RK (8300 SS) (CEMENTED) 8. 11680 MD PERFS AT 60° PHASE, 6 SPF, 20-30' THRU TUBING/CASING. 9. 12800 MD CEMENT CIRCULATED THROUGH TUBING PERFORATIONS ON BACK SIDE UP TO 7500' MD 10. 12960-13508 MD SADLEROCHIT 11. 13100 CEMENT (14 ppg) PLACED OVER PERFORATIONS AND OVER ORIFICE VALVE, (13131 MD) 12. 13244 MD-- BAKER 'DB' PACKER, 13. 13158-13388 MD-- PERFORATIONS IN TUBING ABOVE/BELOW (13158- 13188 ABOVE, 13275-13305 BELOW) PACKER TO ALLOW CEMENT TO BE SQUEEZED IN AREA 14. 13304 MD - TOP OF 7" X 29# L-80 LINER 15. 13532 ELMD - OTIS 'XN' NIPPLE , 3.725"1D 16. 13543 ELMD - BAKER SHEAR OUT SUB/TT, 4.0"ID 17. 13590 MD - 9-5/8" x 47# L-80 CASING 18. WAHOO 7 PERFS 3-3/8" TT 0° PHASE (8656-8725' SS) 13706, 12, 17, 26, 34, 45, 50, 58, 64, 72, 85, 91, 95, 99 13807 19. WAHOO 6 PERFS 3-3/8" TT 0° PHASE (8732-8854' SS) 13817, 22, 34, 82, 84 13920- 13997 2JSPF 180° 20. 13938' MD - PBTD (6-16-90). FILL CONSISTS OF SAND/BALLS ON TOP OF BRIDGE PLUG. 21. WAHOO 5 PERFS 2 JSPF 180° (8854-8875' SS) 13997- 14030 MD 22. SQUEEZE PERFS 6 SPF 13945-1395O 23. WAHOO 4 -NOT PERFORATED 24. FISH -- 1-1/2" McMURRY ORF. GLV w/RK LATCH. LOST 2/20/90. 25. 14375 MD-- TD HOLE ANGLE THRU WAHOO: 47 DEGREES MAXIMUM HOLE ANGLE: 62 DEGREES @ 8500 MD RECEIVED Ancho~'aae Lisburne Well L3-01 Reason for Plug and Abandonment Well L3-01 was drilled and completed as a 4 1/2 inch single completion of Wahoo zones 7 through 5 in October, 1989. The well was subsequently plugged back on June 16, 1990 with a bridge plug set at 13938 feet MD above the Wahoo 5 zone. A leak in the 9 5/8 inch casing has been identified and is allowing cross flow of water from the Cretaceous formation into Wahoo zones 7 and 6. This well has cumulatively produced 571 MSTBO. An extensive study of the remaining reserves in this area indicate that since the last production from the well was at a GOR in excess of 36000. reuse or repair of the existing wellbore is not warranted. Therefore, plugging and abandonment of this wellbore is recommended. Plug and Abandonment Procedure This plug and abandonment plan is designed to accomplish the following specific objectives in compliance with AOGCC regulations: 1.) Isolate the productive intervals of the Lisburne Wahoo formation. 2.) Ensure the isolation of the Sadlerochit formation from the Cretaceous formation. 3.) Isolate the Cretaceous formation· This abandonment procedure is impacted by the 9 5/8 inch casing leak that allows Cretaceous water to crossflow into the Lisburne Wahoo formation, indications that scale exists in the tubing above and mostly likely in the orifice valve located at 13131 feet MD, and finally by a cement bond log indicating limited cement bond across the Sadlerochit formation. The P&A is planned as follows: · Clean scale out of tubing with CTU. (Work was performed in early June, 1994). RECEIVED JUL-'1 1994 {')JJ & Gas Cons. Commission Anchora~je . . . o . . o o Perforate through the tubing at 13275-13305 ft MD for 30 ft with four shots per foot at 90 deg phasing. Also, perforate through the tubing at 13188 ft MD for 30 ft at 6 shots per foot with 90 deg phasing. Using coil tubing, over displace well with ~300 barrels or more of seawater to displace gas away from wellbore. Lay in cement from 13938 ft MD to 13100 ft MD. Cement (Class G W/ 30% 20/40 Sand + 10# Nutplug M + D79 extender) (14 ppg) will cover Lisburne formation up/over bottom orifice. WOC 7 days. Tag cement location at 13100 ft MD. Pressure test tubing. ~H.,.ay_~_ .... AQGC. C ..... ~itness ........ p_o~ ~p~a,_tion for tag verification and pressure test. Pull ported valve at 7108 MD and re-run dummy. Pull SSSV at 2304 MD if not previously done. Perforate tubing at 12800 ft for 20 ft at 4 shots/ft with 90 deg 'i3ha'sing. Bullhead heavy weight brine (10.3 ppg) followed by cement (Class G w/ 10# Nutplug F + 10# Nutplug M) (14 ppg) down tubing. Volume of heavy weight brine (10.3 ppg) will be calculated to occupy the tubing by 9 5/8 inch annulus from surface to 7500 ft. Volume of cement will be calculated to cover from 12800 ft up to 7500 ft on casing side. Cretaceous interval is measured from 8300 to 10400 ft MD. Chase cement with brine for clearing tubing down to 12800 ft MD. Hold pressure on tubing to prevent U-tubing fluids. WOC 7 days. . · Tag cement location in tubing using slickline. Have AOGCC witness on location for tag verification and pressure test. preSsure test casing to insure cretaceous leak has been stopped from coming into wellbore. Shoot fluid level in annulus for check of plug depth. Perforate using 60° deg phase, 6 spf through tubing and casing (~20-30 ft.) at 11680 MD between the Sadlerochit and Cretaceous. Verify that perforations went through to outer 9 5/8 inch casing cement by bullheading brine water into formation. If pressuring up occurs, then acid will be pumped to breakdown the cement. Bullhead cement squeezing the perforations RECEIVED JUL - 1 1994 /~,~.~,-~ Oil & Gas Cons. Commission between the Sadlerochit and Cretaceous using cement, Class G (15.7 ppg). Continue to squeeze perforations, behind casing and leave cement up in tubing to 7500 ft MD. Follow with 10.3 ppg brine from 7500 ft to surface. WOC 5 days. 10. Tag cement location in tubing. Have AOGCC witness on location for tag verification. 1 1. Have AOGCC witness that the 13 3/8 inch will pressure test to 2000 psi. Obtain waiver for additional cementation. 12. Cut 4 1/2 inch tubing at 165 ft or greater below ground elevation, i.e. 205 ft. 13. Remove cut 4 1/2 inch tubing using crane. 14. Make junk bailer run down to 230 ft. Run 9 5/8 inch bridge plug down to 165 ft or more below rig grade elevation, i.e. 205 ft. AOGCC witness to be on location for verifying plug location. Note: If new technology is available, slickline will be used to run gauge run for checking to insure casing is clear for bridge plug setting and for setting of the bridge plug. 15. Circulate cement from 205 ft MD to surface. This lays Arcticset III cement (15.7 ppg) above the 9 5/8 inch bridge plug. 16. Remove wellhead. 17. Dig out around the cellar to 5 ft below,g[ound level. Cut off all · . O~f ~aslng~ strings at leas~. 3 .ft ....... belo, wZgr,o~u~gd 1,..e. yel. -~-end the ~ellhe~d ~0~"'brill"Site Maintenance. The gravel pad should be 5 ft thick. 18. Weld steel plate on top of cemented casing strings with detailed well information per 20 AAC 25.120 6 d. This procedure must be witnessed by AOGCC. ARCO Alaska, Inc. Prudhoe Bay Unit Lisburne Well L3-01 287' FNL, 550' FWL, Sec. 22, Tl lN, R15E, UM RECEIVED ~iJL. 1 199~, Ai~.ska {iii & Gas Cons. Commission Anch0r'a~e 19. Back fill the excavation. Submit a report of all activities to Lisburne/Point McIntyre Operations Engineering so that the necessary paperwork may be filed with the AOGCC. RECEIVED Gas Cor~s. Corr~mission Anchorau~ L3-01 Plug and Abandonment Procedure · Waivers Requested Part of the Lisburne perforations have a mechanical bridge plug and part of the perforations will be displaced with cement across them. Variance is requested on 20 AAC 25.105 part H (1) (A) and (C) as part of the perforations are done by one method and part of_ ¢~~ the perforations are done by another method. · · Weld steel plate on top of casing with well information rather than marker-post installation. If requested by the operator or surface owner, the marker post installation requirement will, in the commission's discretion, be waived by the commission. If the requirement is waived, the information required in b 1, 2 and 3 of this section must be bead-welded on top of a steel plate secured to the casinghead. Variance is requested under 20 AAC 25.120 d, pg. 20 of Alaska Oil and Gas Commission Regulations Request waiver on 13 3/8 inch casing cementation. Pressure tested 13 3/8 inch casing on May 15 up to 2000 psi. Casing held pressure for 15 minutes with no leak-off. no paperwork regarding the ArcticPac of the well. requested. We have Waiver is RECEIVED ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 July 30, 1993 Ms. Joan Miller AOGCC 3001 Porcupine Drive Anchorage, AK 99501 FIE: Delinquent Subsequent Sundry Notices Dear Madam: Enclosed are delinquent subsequent sundry notices for the Lisburne Oil Pool. Please refer to the list below. Form 10-404 W¢_I Permit Approval Date Description Comment L1-15 89-132 90-314 5/8/90 Stimulate Completed L1-30 90-18 90-798 11/1/90 Peri/Stimulate " L2-06 83-47 9-928 10/20/89 Install Kinley Buttons " L2-10 87-85 90-850 12/3/90 Stimulate " L2-16 87-97 90-865 12/13/90 Stimulate Job Canceled L2-18 87-118 90-851 12/13/93 Peal/Stimulate Completed L2-30 85-9 9-955 11/1/89 Install GLVs " L3-01 1~--15'~ 1 90-779 10/16/90 Acid Wash " L3-28 89-66 90-807 11/9/90 Peri/Stimulate " L4-03 88-67 91-248 8/27/91 Peal/Stimulate " L4-15 83-71 91-308 10/16/91 Stimulate " L4-30 88-101 90-800 10/24/90 Stimulate " L5-12 87-10 90-781 10/16/90 Stimulate " L5-21 87-57 90-609 8/9/90 Stimulate " ~.-..-~'.~ ~.>'~-/> / ¢:~- ? "/] I .--ex, .x~-:.~.~.¢'::~,,,~.~,.~;/~;- /' ~, '2/t' Sincerely, George K. Phillips Engineering Supervisor Lisburne/Point Mclntyre Engineering GKP:LSL:jb Enclosures cc: R.G.M. Oba, ARCO Alaska, Inc. (Without Enclosures) R ECE \/E D A U -' 6 1993 Alaska Oil & Ga:; Cons, Oommissio~'~ Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .' REPORT OF SUNDRY WELL OPERATIONS " ~ Plugging Perforate _ Pull tubing . Other . 5. Type of Well: 6. Datum elevation (DF or KB) Development X 1. Type of Request: Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alasks, In(;:;. Exploratory Stratigraphic Service 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 287' FNL, 550' FWL, Sec.22, T11N,R15E, UM At top of productive interval 1553' FNL, 2482' FWL, Sec.9, T11N,R15E, UM At effective depth 1106'FNL, 2341' FWL, Sec.9, T11N,R15E, UM At total depth 1072' FNL, 2331' FWL, Sec.9, T11N,R15E, UM Present well condition summary Total Depth: measured 1 4375' feet true vertical 91 72' feet RKB 60' 7, Unit or Property name Prudhoe/Lisburne Unit 8. Well number L3~01 9. Permit number/approval number 89-75/90-24.5 10. APl number 50-029-21~.~)-00 11. Field/Pool LISBURNE OIL POOL Plugs (measured) NONE feet 12. Effective depth: measured 14326' feet true vertical 91 3 8' feet Junk (measured) NONE Casing Le n g t h Size Structural Conductor 8 0' 2 0" Surface 5 2 2 6' 133/8" Intermediate 1 3555' 95/8'' Production Liner 1 064' 7" Cemented Measured depth 2150# Pdeset 1 1 5' 3500 sx ASIII & 5264' 500 sx Qa~sG- Topi cbw/175 sx ASI 500 sx SSII 13590' 184 sx ARC(Oass(~ 13304-14368' True vertical depth 115' 3993' 8640' 8462-9167' Perforation depth' measured 13706~13799', true vertical 13807-13884' 13920~14030' Tubing (size, grade, and measured depth) 41/2'', L-80, tbg w/tail @ 13579' Packers and SSSV (type and measured depth) Baker 'DB' pkr @ 13244', 'HRQ' SSSV @ 2304' 13, Stimulation or cement squeeze summary intervals treated (measured) Wahoo zones 7 & 6. Treatment description including volumes used and final pressure Please refer to the attached. 14. R.epresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 384 3614 1 5 50 454 874 -~' 7389 46 50 445 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations ~X 16. Status of well classification as: Water Injector Oil .X Gas . . Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, led e K. Phillips Title Engineering. Supervisor-Lisb/Pt Mc Form 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE Lisburne Well L3-01 Perforation/Stimulation Procedure 5/24/90 Shut in well. Rigged up and shot fluid level on 95/8 for CFA. 5/25/90 Pulled gas-lift valves. 5/27/90 Initial attempt to set inflatable bridge plug (IBP) failed. IBP. Fished and retrieved 5/28/90 Set IBP and dumped 2 bbl sand on top in preparation for CFA job. 6/3/90 Rigged up service company to pump stimulation fluids. Acidized Wahoo 7 and upper Wahoo 6 with the following stimulation fluids: · 200 BBL 15% Gelled HC1 · 475 BBL Uncrosslinked 40 pptg gel w/ball sealers · 300 BBL Emulsified Acid w/ball sealers · 225 BBL Gelled Diesel · 850 BBL Crude/Diesel Overflush Released service company. (Well control was provided by surface chokes and production valves). Attempts to retrieve IBP failed. Opened well to flow. APPr. ICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter ~uspended well _ 2. Name of Operator ARCO Alaska. I,no, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 287' FNL, 550' F'VVL, Sec. 22, T11N, R15E, UM At top of productive interval 1553' FNL, 2482' FVVL, Sec. 9, T11N, R15E, UM At effective depth 1106' FNL, 2341' FVVL, Sec. 9, T11N, At total depth I 2331' FVVL, Sec.. 9, T11N, 12. Present well condition summary Total Depth: measured true vertical Alter ca~ing RePair well _ Plugging _ Change approved program _ Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphi¢ _ R15E, UM R15E, UM 1 4375' feet 91 7 2' feet Time extension Stimulate X Variance PeHorate Other 6. Datum elevation (DF or KB) RKB 60' 7, Unit or Property name Prudhoe Bal~ Uni[tLisburne 8. Well number L3-01 9. Permit number 10. APl number 5o-029-21959-00 11. Field/Pool Lisburne Oil Pool Plugs (measured) feet Effective depth: measured 14326' feet Junk (measured) true vertical 9138' feet None 13. Casing Length Size Structural Conductor 8 0' 2 0" Surface 5 2 2 6' 1 3 - 3 / 8" Intermediate Production Uner Perforation depth: 13555' 9-5/8" 1064' 7" measured 13706-13799', 13807-13884' 13920-14030' Wahoo 6/5 true vertical Tubing (size, grade, and measured depth 4-1/2", L-80, tbg w/tail @ 13579' Packers and SSSV (type and measured depth) Baker 'DB' 13244', 'HRQ' SSSV 2304' Attachments Description summary of proposal _ Cemented Measured depth True vertical depth 2150# Poleset 1 1 5' 1 1 5' 3500 sx AS III & 5264' 3993' 500 sx Class G - Top job w/175 sx AS I 500 sx SS II 13590' 8640' 184 sx ARC (Class G) 13304-14368' 8462-9167' Wahoo 7 RECEIVED APR 1 8 ]990 A~ka.Oi] & Gas Cons, Commissl~r~ ~ Anchorage Detailed operation program ~ BOP sketch _ 14. Estimated date for commencing operation J 15.' Status of well classification as: May 1, 1~)~0 [ ' Oil ~ Gas __ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended Title Em Aide FOR COIV~ISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity_ BOP Test_ Location clearance m Mechanical Integrity Test_ Subsequent form require 10- IApproval No.~(::) the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIF C, SMITH Approved Copy Returned Commissioner SUBMIT I1~ TRIPLICATE le 2, . . Se . . ATTACHMENT 1 WELL L3-01 Shut in well. Rig up and pressure coiled tubing lubricator (see attached schematic). RIH w// inflatable Bridge Plug set at 13,900' MD. Acidize Wahoo 6 and 7 with the following: 50 bbl dispersed acid w/20 ball sealers. 150 bbl 15% gelled HCl w/30 ball sealers. Flush with 200 bbl crude followed by 100 bbl diesel. (Max. treating pressure = 4800 psi) Release service company, open well to flow. Retrieve inflatable bridge plug. RECEIVED APR ! 8 19,90 A~aska Oil & Gas Cons~ Commissior~ Anchorage 6 ,5 4 2 I ! COILED TUBING UNIT BOP EOU 1 PMEN~ 1. ~)00 PSI ?" WELLHEAD CONNECTOR FLANGE 2. ~)00 PSI 4 1/16" PIPE RAMS 3. ~)00 PSI 4 1/6" I'IYD~L~ SLIPS 4. 5000 PSI 4 1/6" SH~ RAMS 5. ~d:)O0PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFINO BOX HIRELINE BOP EOUIPMENT _ _ 1. 5000 PSI ?" WELLHEAD CONNEC10R FLANGE 2. 5000 PSI WIRELIN[ RAIaS (VARIABLE 3. ~,000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF J WELL L3-O1 SCHEMATIC APl ~ $0-029-21959 ~3 I 12 10 11 Well Status: Producer 9fl qas lift surface Location: 287FNL,549FWL,Sec22,T 11N,R 15E,UM Top Lisburne Loc: FNL,FEL,Secg,T 11N,R 15E,UM RKB To Tubing Hanger: 35 Feet Top of Wahoo: 13687 MD/ 8543 SS Datum: 14067 MD/8900 SS Reference Log:Z-Density/CN(Porosity), 08/12/89 Annulus Fluid: 8.5 ppg Sea Water below 7108' MD. · Spud Date: 7- 14-89 Completion: 10-24-89 Minimum ID: 3.725"@ 13555' MD GAS LIFT DEPTH 3256 MD 7108 MD 10278 MD 12431 MD 13131 MD 5. 6. 7. 8. 9. 10. WAHOO 7 1.35 MD -- 4-1/2" TBG HANGER, 4-1/2"X 12.6~, L-80, IPC 2. 2304 MD--OTISSSSV'HRQ' BVLN, 3.813"ID-WIRELINERETRIEVABLE 3. 5264 MD--13-3/8" x 68~, L-80 CSG. SET 4. MANDRELS MANDREL TYPE VALVE LATCH TRO McMURRY 1 - 1/2"FMHO DUMMY RK McMURRY 1-1/2"FMHO 1/4"port RK ~70 McMURRY 1 - 1/2"FMHO DUMMY RK McMURRY 1 - 1/2"FMHO DUMMY RK McMURRY 1 - t/2" FMHO 5/16" ORF. RK ,, ~ 13244 MD - BAKER 'DB' PACKER, 13284 MD - TOP OF 7" X 29~ L-8OLINER 13532ELMD-OTIS'XN'NIPPLE, 3.725"1D 13543 ELMD - BAKER SHEAR OUT SUB/TT, 4.0"ID 13589 MD - 9-5/8" x 47~ L-80 CASING 3-3/8" TT O' PHASE SS DEPTH (2753 SS) (5004 SS) (6699 SS) (7899 SS) (8300 SS) (8656-8776'5S) 13706, 1~, 17,~6,34,45,50,~8,64,7~,85,91,9~,99 13807, 17.22,34,8~,84 ll. WAHOOS/6PERFORATIONS 2JSPF 180' 13920-14030 MD 12. SQUEEZE PERFS 6 SPF 13945-13950 13. WAHOO 4 -NOT PERFORATED 14. FISH -- 1-1/2" McMURRY ORF. GLV w/RK LATCH. LOST 2/20/90. 15. 14006 ELMD-- PLUG BACK DEPTH (TAGGED 1 / 17/90) 16.14368 MD--TD (8800-8875'S5) HOLE ANGLE THRU WAHOO: 47 DEGREES MAXIMUM HOLE ANGLE: 61 DEGREES @ 6500 MD Max. H2S Measured = 60 PPM (ON GAS LIFT) - CALCULATED = 160 PPM (FORM GAS ) Revision Date: 4-9-90 (3) DATE: 3/21/90 FROM: TINA KINCAID ARCO ALASKA INC. LlSBURNE ENGINEERING ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: 1/30/90 1/30/90 1/30/90 3/15/90 2/21/90 2/21/90 2/21/90 2/12/90 L1-15 GCT RUN2 L1-15 CEMENT EVALUATION (CE'I) RUN 1/3 L1-15 CEMENT BOND LOG RUN 1/3 L1-15 PFC RUN1 L1-30 GCT RUN 1 L1-30 CEMENT BOND LOG RUN 1 L1-30 CEMENT EVALUATION (CET) RUN 1 L1-30 Z-DENSILOG COMP NEUTRON RUN 1 (POROSITY) Z-DENSILOG COMP NEUTRON (RAW DATA) L1-30 DUAL LATEROLOG RUN 1 L1-30 FORMATION MULTI-TESTER RUN 1 L1-30 SPECTRALOG RUN 1 L1-30 PHYSCIAL FORMATION RUN 1 L1-30 GAMMA RAY RUN 1 L3o01 PERFORATING RECORD RUN 1 L4-02 COLLAR LOG RUN 1 L4-10 PFC RUN 1 L4-31 PERFORATING RECORD RUN 1-9 L1-30 RUN I 2/12/90 2/12/90 2/12/90 2/12/90 2/11/90 2/1/90 1/17-18/90 3/10/90 3/1/90 2/14/90 SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER ATLAS SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER ATLAS ATLAS ATLAS ATLAS ATLAS ANADRILL ANADRILL HALLIBURTON ATLAS ATLAS SCHLUMBERGER RECE ¥EO MAR ~ 2 !990 0ii & Gas Cons. Cor~$ts~,og--"= Anchorage ORIGINAL STATE OF ALASKA AL ...,KA OIL AND GAS CONSERVATION CL~,~-vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r~ GAS [~] SUSPENDED E~ ABANDONED F'"] SERVICE r-~ 2 Name of Operator 7 Permit Number ARCO Alaska. Inc 89-75 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21959 4 Location of well at surface 9 Unit or Lease Name 287' FNL, 550' FWL, SEC 22, T11N, R15E UM ~::~'i~:":~'~ ~-'~~'',.~ PRUDHOE BAY UNIT AtTop Producing Inte~al ~ ~ ~;~.. ,;:;.~ ;~ 10 Well Numar 1553' FN L, 2482' FWL, SEC 9, T11N, R15EU M ~ ,~.:~ .... ;~ L3-1 .1072' FNL, 2331' FWL, SEC 9, T11N, R15E UM PRUDHOE BAY FIELD/LISBURNE 5 Elevation in feet (indicate KB, DF, etc.) 6 L~se Designation and Serial No. LISBURNE OIL POOL RKB 60' ADL 34631/ALK 865 12 0ate Spudded 13DateT. D. Rea~hed 14 DateComp.,SusD. orAband.~ ~ ~[lfiWator~op~,ifoffshoro II~ ~o.o[Go~plotio~s 7/14/89. 8/1~89. ~ --//~r/~_ N/A feetMSL 1 17 Total Dep~ (MD+~D) 18 Plug Back Depth (MD+TVD) 19 Directional Suwey 20 Depth where SSSV set 21 Thickness of permafrost 14375' MD/9172' TVD 14326' MD/91~' TVD YES ~ NO ~ 2304' feet MD 1900' (approx) 22 Ty~ El~tric or Other Logs Run GR/DLUSPECTRALOG/REL, ZDUCNUGR/CAL, GR/FMT, CET/CBT/GR/CCL, GCT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~ ~LE SIZE CEME~tNG RECORD AMOUNT PULLED 20" 91.5~ H-40 SURF 115' 30" 2150~ POLESET 13-3/8" 68.0g K-55/L-80 SURF 5264' 17-1/2" 3500 SX AS III & 500 SX CLASS G-TOP JOB W/175 SX AS 9-5/8" 47.0~ L-80 SURF 13590' 12-1/4" 500 SX C~SS G 7" 29.0~ L-80 13304' 14368' 8-1/2" 184 SX ARC (C~SS G) 24 Perforations open to Production (MD+~D of Top and BoEom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 13579' 13244' SEE ATTACHED 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH I~ERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13945'-13950' 20 BBL 15% HCI & 93 SX CLASS G 27 N/A PRODUCTION TEST Date First Production ~Method of Operation (Flowing, gas li~ etc.) I Date of Test Hours Test~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ FiowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR ~TE ~ 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent di~ and presence of oil, gas or water. Submit core chips. *NOTE: DRILLED RR 8'19'89. TUBING RUN · WELL ACIDIZEO THEN SQUEEZED 10'25'89. PERFORATED WmLL 1 '/;,~,~, ~.;1,~,&~,:::~' ~. FRACTURE PERFORMED 1~4/89. ~ '~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase, TO P WAHOO ZONE 7 13687' 8704' TOP WAHOO ZONE 6 13812' 8787' TO P WAHOO ZONE 5 13997' 8912' FMT DATA: TOP WAHOO ZONE 4 14120' 8996' DEPTH HYDRO. PRESS SHUT-IN PRESS (FT) (PSI) (PSI) 13694 4206 3535 13709 4199 3467 13735 4204 3380 13744 4198 3452 13758 4205 3582 14116 4374 4233 31. LIST OF ATTACHMENTS ADDENDUMS (DATED 8/26/89,11/29/89, 12/4/89, & 1/17/90) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ~~~ Title pRILLING ANALYST Date ~-~/*~) 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Item 24. Well Completion or Recompletion Report L3-1 continued Perforation depth' IVD ,T,,VD Pe rforate w/ 1 spf, 0° phasing 13706 8716 13712 8720 13717 8723 13726 8729 13734 8735 13745 8742 13750 8746 13758 8751 13764 8755 13772 876O 13785 8769 13791 8773 13795 8776 13799 8778 138O7 8784 13817 8791 13822 8794 13834 8802 13882 8835 13884 8836 Perforate w/ 2 spf, 180° phasing 13920-14030 8860-8934 and Log WELL WORK LOG ADDENDUM Well # L3-1 Date: 1/17/90 Work performed: ADD PERF WAHOO 6 & 7 Cost: $19,062.00 AFE: AL0923 Time Summary O73O 0840 1000 1140 1245 '1300 1310 1330 1510 1645 1910 2220 MIRU Halliburton PT bops to 3500 psi & lub to 3000 psi RIH w/ Gun #lA & lB, 3-3/8 tru-jet, LSD, 0° phasing. Set down @ 2880', could not get by. Start pumping 180° diesel down tubing R=I bpm @ 900 R=1.4 bpm @ 750 psi V=66 R=l.4bpm@ 750 psi V=84 - Re arm gun 'SD HB&R V=100 bbl diesel RIH w/Gun #1 - No problems. Tie in. Ref CET (10/23/89) Shoot Gun #lA @ 13882, 84 & Gun #lB @ 13817, 22, 34. Log up. All shots fired RIH w/ Gun #2. Shoot @ 13791,95,99,13807. Log up. All shots fired RIH w/Gun #3. Shoot @ 13758,64,72. Log up. All shots fired RIH w/Gun #4A & 4B. Shoot 4A @ 13785, & 4B @ 13734,45,50. Log up. All shots fired 1/18/90 0105 0330 RIH w/Gun #5. Shoot @ 13706,12,17,26. RD HLS, Secure well. Log up. All shots fired DRILLING SUPERINTENDENT ADDENDUM WELL WORK LOG Well Date: 1 2/4/89 Work performed: FRACTURE Cost: ~;94.696.13 AFE: AL0923 Time Summary 04O0 0700 1110 1400 1440 1500 1515 1519 1531 1540 1544 1557 1600 1620 1630 1 73O DRILLING SUPERINTENDENT Start gelling water Prep tree saver, rig up pumps. Stab & bolt-up tree saver - 45 bpm rate max. allow. Tree saver set & static tstd, cont rig-up.Gel ready for tstg, ok, 2 min x-link"Borate" Primcpump & purge lines. PT treating lines 7800# OK PT back side lines. Press 9-5/8 from 1800# to 2800#, run pump against trips set at 6100#. OK Hold safety mtg. Open well 800# WHP, 2750# 9-5/8 Pump 40 PPT gel for meter test. 20 bpm, 3200# WHP 75 bbls away (meter) shut down. Strap= 75 bbls, ISIP @ 2146# Start job w/ x-linked 40 PPT "hybor 1400" system, 200 bbls away, 44 bpm, 5050# WHP, 3100# 9-5/8 - 300 bbls away, 44 bpm, 5050# WHP, bleed 9-5/8 from 3150# to 3050# 336 bbls away, at 117 bbls in formation, tripped high press at 6000#, drop rate to 15 bpm, 5000# WHP 419 bbls away, cut cross linker, 5200# at 16 bpm treating press. Decreasing x-linked gel pumped away, increase rate, make 41 bpm at 4750# WHP 750 bbls away,x-link gel displaced by at 112 bbls non-x-linked gel,ISIP at 3054# WHP=2000#, 9-5/8=2938#, freeze protect well w/ 60/40 meth/wtr, 3.75 bpm at 2600# 50 bbls 60/40 away, shut down, at 3250' freeze protect. Bleed 9-5/8 to 2000# Flush pumps & hard line w/diesel at 50 bbls, 1600 bbls 40# gel on surface. Blow down lines. Discuss w/town engineer Rig down. Master valve closed, tree saver off well. Pumped: 406 bbls gel 420 bbls x-linked 40# gel 50 bbls 60/40 meth/water 50 bbls diesel ADDENDUM WELL WORK LOG Well # L3-1 Date: Work performed: INITIAL PERF 110' Cost: $19.500.00 AFE: AL0923 Time ~;ummary 0700 0830 0905 1050 1230 1340 1510 1620 1800 1905 2030 2140 2245 MIRU Atlas WL PT bops to 3500 psi & lub to 3000 psi RIH w/ gun #1, 10' @ 2 spf, 180° phasing. Log collars, shoot f/ 14020'-14030'. POOH. RIH w/gun Log collars, RIH w/gun Log collars, RIH w/gun #4, 20' @ 2 spf, 180° phasing. Log collars, shoot f/ 13960'-13980'. POOH. RIH w/gun #5, 20' @ 2 spf, 180° phasing. Log collars, shoot f/ 13940'-13960'. POOH. RIH w/gun #6, 20' @ 2 spf, 180° phasing. Tie in CET (10/23/89) All shots fired #2, 20'@ 2 spf, 180° phasing. Tie in. shoot f/ 14000'-14020'. POOH. All shots fired #3, 20'@ 2 spf, 180° phasing. Tie in. shoot f/ 13980'-14000'. POOH. All shots fired Tie in. All shots fired Tie in. All shots fired Tie in. 11/30/89 O030 0300 Log collars, shoot f/ 13920'-13940'. POOH. All shots fired Job complete Interval: 13920'-14030' w/ 2spf, 180° phasing DRILLING SUPERINTENDENT ADDENDUM DAILY DRILLING REPORT Well # L3-1 Date: 8/26/89 Work performed: LOGGIN(~ Cost: $34.509.00 AFE: AL0923 Ran CET/CBT/GR f/ 14319'-7950' @ 0 psi Ran CET/CBT/GR f/ 14319'-12300' @ 1000 psi - 7" liner cmt appears to have a cmt channel on Iow side. 9-5/8" cmt quality poor. Was still poor spotty cmt at 7950' when logging stopped. Question it it is actually cmt that was being picked up on sensors. Ran GCT survey f/ 14242'-surf. Showing well to be +_650' to the west of MWD. DRILLING SUPERINTENDENT $ UB.$ URFA CE DIRECTIONAL ~]UIDANCE sunV IcilOFILMED [~ONTINUOUS r~OOL Company ARCO ALASKA I NC. Well Name Field/Location PRUDHOE BAY/LISBURNE POOL NORTH SLOPE ALASKA Oat...._~e Job Reference No. 26-AUG-89 73494 Computed By;, WARNER KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. L3-1LISBURNE PRUDHOE OAY/LISEURNE POOL NORTH SLOPE9 ALASKA SURVEY DATE: 26-~UG-Sg ENGINEER: W~RNER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND ~ZIMUTH INTERPOLATION: LINEAR ',i, ' VERTICAL SECTION: HORIZ. DISTo PROJECTED ONTO Ak TARGET AZIMUTH OF NDRTH 15 OEG g MIN WEST COMPUTATION DATE: 03-0CT-89 PAGE I - ARCO ALASKA, TNCo L3-1LISBURNE PRUOHOE BAY/LISBURNE POOL NORTH SLOPE, AL.~SKA DATE DF SURVEY= /6-AUG-89 KELLY BUSHING ELEVAT[ON: 60.00 FT , ENGINEER: WARNER INTERPOLATED VALUE,S FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VF::RTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN D~G MIN 0.00 0.00 -60.30 0 0 N 0 0 E 100.00 100.00 40.00 0 2 S 67 3 E 200.00 200.00 140.00 0 3 N 31 1'~ W 300.00 300.00 240.00 0 21 S 58 37 W 400.00 399.99 339.99 0 41 S 56 35 W 500.00 499.99 ~39.99 0 35 S 71 4 W 600.00 599.92 539.92 4 2 N 21 15 W 700.00 699.53 639.53 5 55 N 11 4'3 W 800.00 798.66 738.66 8 55 N 7 23 W 900.00 897.25 837.25 10 38 N 7 4 W 1000.00 995.15 935.15 12 47 1100.00 1092.10 1032.10 15 1.6 1200.00 1188.24 1128.24 16 37 1300.00 1283.59 1223.59 18 49 1400.00 1377.31 1317.31 21 47 1500.00 1469.48 1409.48 23 46 1600.00 15.60.30 1500.30 25 42 1700.00 1649.87 1589.87 26 56 1_800.00 1738.40 1678.40 28 42 1900.00 1825.42 1765.42 30 12 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE ' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 2000.00 1911.05 1851.05 32 19 2100.00 1993.88 1933.88 36 5 2200.00 2072.99 2012.99 38 58 2300.00 2149.40 2089.40 41 '9 2400.00 2224.55 2164.55 41 8 2500.00 2300.07 2240.07 40 54 2600.00 2374.61 2314.61 43 6 2700.00 2447.04 2387.04 43 15 2800.00 2519.79 2.459.79 44 5 2900.00 2590.16 2530.16 46 31 0.00 O.OO 0.00 N O.CO E 0.04 0.38 0.04 N 0.02 E -0.01 1.36 0.02 N 0.14 E -0.25 0.80 0.37 S 0.40 W -0.49 0.09 0.79 S 1.02 W -0.80 0.26 1.37 S 1.97 W 1.68 3.21 0.73 N 3.75 W 10.49 2.96 9.23 N 6.04 W 23.43 1.31 22.08 N 8.09 W 39.95 2.17 38.64 N 10.17 W N 7 33 W 60.12 N 8 1 W 84.40 N 9 33 W 111.72 N 12 14 W 141.75 N 13 ,8 W 176.56 N 12 34 W 215.29 N 11 50 W 257.08 N 11 57 W 301.46 N l/ 44, W 347.90 N 14 15 W .397.14 3000.00 2657.33 2597.33 49 20 3100.00 --.720.38 2660.38 52 11 3200.00 2780.37 2720.37 53 50 3300.00 2838.3¢ 2778.34' 55 18 3400.00 2895.12 2835.12 54 53 3500.00 2953.27 2893.27 54 10 3600.00 3012.35 2952.35 53 12 3700.00 3072.35 3012.35 53 47 3800.00 3131.48 3071.48 52 38 3900.00 3193.32 3133.32 51 28 N 15 33 W 448.76 N 16 25 W 504.74 N 19 8 W 565.82 N 21 8 W 630.05 N 21 49 W 695.61 N 21 57 W 760.69 N 20 43 W 826.93 N 18 9 W 895.66 N 16 37 W 964.23 N 15 42 W 1035.25 N 14 39 W 1109.32 N 13 44 W 1186.90 N 13 30 W 1266.87 N 14 43 W 1348.33 N 16 0 W 1430.64 N 20 34 W 1511.84 N 21 39 W 1592.02 N 22 34 W 1671.45 N 23 17 W 1751.31 N 23 4 W 1829.13 2.08 58.83 N 1.67 83.11 N 1.59 110.28 N 2.89 139.86 N 2.43 173.80 N 2.09 211.58 N 1.84 252.49 N 1.26 296.01 N 1.96 341.45 N 1.73 3.89.36 N 3.04 3.75 3.20 1.26 0.38 1.00 2.81 2.46 2.04 2.70 3.31 2.47 1.29 1.33 3.10 3.20 1.61 2.12 2.61 0.63 0.00 N 0 0 E 0.04 N 20 10 E 0.14 N 80 14 E 0.55 S 47 23 W 1.29 S 52 30 W 2.40 S 55 15 W 3.82 N 79 4 W '~, 11.03 N 33 13 W ., 23.52 N 20 8 W 39.95 N 14 44 W 12.74 W 60.19 N 12 13 W 15.98 W 84.64 N 10 53 W 20.20 W 112.11 N 10 23 W 25.83 W 142.22 N 10 28 W 33.69 W 177.03 N 10 58 W 42.36 W 215.78 N 11 19 W 51.13 W 257.62 N 11 27 W 60.23 W 302.08 N 11 30 k 70.10 W 348.5T N 11 36 W 31.52 W 397.80 N 11 50 W 439.22 N 94.91 W 449.36 N 12 12 W 493.07 N 110.25 W 505.24 N 12 36 W 551.33 N 128.77 W 566.17 N 13 9 W 611.80 N 151.20 W 630.21 N 13 53 W 673.16 N 175.43 W 695.64 N 14 36 W 733.95 N 199.93 W 760.69 N 15 14 W 795.96 N 224.35 W .826.98 N 15 44 W ,) 860.90 N 247.48 W 895.77 N 16 2 W 926.48 N 267.63 W 964.35 N 16 7 W " 994.70 N 287.45 W 1035.40 N 16 7 W 1066.18 N 306.83 W 1109.45 N 16 3 W 1141.43 N 325.78 W 1187.01 N 15 56 W 1219.24 N 344.39 W 1266.94 N 15 46 W 1298.24 N 364.30 W 1348.39 N 15 40 W 1377.73 N 385.66 W 1430.69 N 15 38 W 1454.96 N 411.14 W 1511.93 N 15 47 W 1530.00 N 440.75 w 1592.22 N 16 4 W 1604.21 N 470.63 W 1671.8Z N 15 21W 1678.38 N 502.27 W 1751.92 N 16 40 W 1750.64 N 533.15 W 1830.02 N 16 56 W COMPUTATION CATE: 03-0CT-39 PAGE 2 ' ARCO ALASKAs INC. L3-1 LISOURNE PRUDHOE 8AY/LZSBURNE POOL NORTH SLOPE~ ALASKA DATE OF SURVEY: Z6-AUG-89 . KELLY BUSHING ELEVATION: 60.00 F'T ENGINEER: WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURS5 MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN BEG MIN VERTICAL DOGLEG RECTANGULAR COORD,IN&TES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3255.35 3195.35 52 16 4100.00 3315.66 3255.66 53 12 4200.00 3375.40 3315.40 53 -4300.00 34,33.78 3373.78 54 27 4400.00 3491.78 3431.78 54 54. 4500.00 3549.16 3489.16 54 43 4600.00 3607.18 3547.18 54 33 4700.00 3665.08 3605.08 54 35 4800.00 3723.14 3663.14 54 28 4900.00 3781.20 3721.Z0 54 32 N 24 43 W 1906.74 N 26 34 W 1985.08 N 28 I W 2063.58 N 29 48 W 2142.31 N 30 42 W 2221.03 N 31 22 W 2299.71 N 31 5 W 2377.98 N 30 50 W 2456.43 N 30 42 W 2534.85 N 30 40 W 2613.30 3.11 0.40 3.08 0.47 1.67 0.91 0.47 0.21 0.1¢ 0.09 1822.59 N 564.3'9 W 1907.97 N 17 12 W 1894.29 N 599.32 W 1986.83 N 17 33 W 1965.77 N 635.65 W 2065.99 N 17 55 W 2036.60 N 675.32 W 2145.65 N 18 21 W 2107.10 N 716.15 W 2225.48 N 18 46 W 2177.10 N 758.66 W 2305.50 N 19 13 W -~, 2246.76 N 800.86 W 2385.23 N 19 37 W ) 2316.70 N 842.77 W 2465.23 N 19 59 W 2386.67 N 884.39 W 2545.26 N 20 20 W 2456.69 N 925.93 W 2625.39 N 20 39 W 5000.00 3839.27 3779.27 54 22 5100.00 3897.69 3837..69 54 11 5200.00 3956.11 3896.11 54 25 5300.00 4014.66 3954.66 53 43 5400.00 4073.73 4013.73 53 41 5500.00 413q.31 4073.31 53 18 5600.00 419].35 4133.3~ 53 10 5700.00 4252.45 4192.45 54 40 5800.00 4309.53 4249.53 55 19 5900.00 ¢366.75 4306.75 54 41 N 30 33 W 2691.76 N 30 21 W 2770.06 N 30 7 W 2848.41 N 30 4 W 2926.76 N 30 3 W 3004.72 N 29 53 W 3082.36 N 29 19 W 3159.76 N 27 13 W 323~.28 N 25 42 W 3318.80 N 24 21 W 3399.58 0.51 0.19 0.45 0.79 0.90 0.49 1 2.29 1.29 2.21 2526.74 N 967.42 W 1705.61 N 20 57 W 2596.74 N i008.51 W 2785.70 N 21 13 W 2666.84 N 10~9.40 W 2865.88 N 21 29 W 2737.02 N 1089.98 W 2946.07 N 21 43 W 2806.84 N 1130.42 W 3025.92 N 21 56 W 2876.41 N 1170.56 W., 3105.47 N 22 9 W 2945.86 N 1210.19 W' 3184.76 N 22 20 W 3016.84 N 12,48.49 W 3264.98 N 22 29 W 3090.38 N 1285.01 W 3346.89 N 22 35 W 3164.64 N 1319.80 W 3428.82 N 22 38 W 6000.00 ,4424.94 4364.94 54 40 6100.00 4482.4=J 4422.48 54 44 6200.00 4539.88 4479.88 55 22 6300.00 4596.86 4536.86 54 54 6400.00 4654.65 4594.65 54 43 6500.00 4712.67 4652.67 54 16 6600.00 4771.1'9 4711.19 54 9 6700.00 4829.86 4769.96 53 58 6800.00 4888.54 4828.54 54 24 6900.00 4946.40 4886.40 54 57 N 22 I W 348D. 13 N 20 42 W 3561.40 N 18 14 W 3643.07 N 17 56 W 3725.14 N iT 49 W 3806.66 N 17 35 W 3888.02 N 17 29 W 3969.04 N 17 14 W 4049.97 N 16 57 W 4130.89 N 16 33'3 W 4212.42 1.35 2.27 1.09 0.81 0.33 0.34 0.20 0.25 0.75 1.00 3239.51 N 1351.52 W 3510.13 N 22 39 W 3315.56 N 1381.59 W 3591.90 N 22 37 W 3392.84 N 1408.66 W 3673.64 N 22 33 W 3471.01 N 1433.98 W 3755.56 N 22 27 W 3548.68 N 1459.04 W 3836.92 N 22 Z1 W 3626.26 N 1483.82 W 3918.10 N 22 15 W 3703.60 N 1508.21 W 3998.92 N 22 9 W 3780.90 N 1532.36 W 4079.62 N 22 4 W · 3858.29 N 1556.15 W 4160.29 N 21 58 W 3936.37 N 1579.73 W 4241.53 N 21 52 W 7000.00 5003.39 4943.39 55 28 7100.00 5059.88 4999.88 55 49 7200.00 5115.50 5055.50 56 38 7300.00 5170.02 5110.02 57 13 7400.00 5223.62 5163.62 57 58 7500.00 5276.20 5216.20 58 32 7600.00 532,9.17 5268.17 58 54 7700.00 5379.34 5319.34 59 32 7800.00 5429.62 5369.62 60 1 7900.00 5479.43 5419.43 60 4 N 16 1 W 4294.57 N 15 46 W 4377.08 N 15 44 W 4460.18 N 15 34 W 4544.01 N 15 8 W 4628.43 N 14 44 W 4713.49 N 14 25 W 4798.92 N 14 12 W 4884.82 N 14 3 W 4971.25 N 14 7 W 5057.95 0.62 0.74 0.88 0.67 O .74 0.39 0.56 0.58 0.20 0.~3 4015.25 N 1602.77 W 4323.32 N 21 46 W 4094.62 N 1625.31 W 4405.40 N 21 39 W 4174.61 N 1647.84 W 4488.07 N Z1 32 W 4255.32 N 1670.51 W 4571.47 N 21 26 W 4336.74 N 1692.82 W 4655.42 N 21 19 W 4418.93 N 1714.71 W 4739.96 N 21 12 W 4501.62 N 1736.19 W 4824.83 N 21 5 W 4584.83 N 1757.39 W 4910.15 N 20 58 W 4668.71 N 1778.48 W 4995.9B N 20 51 W 4752~82 N 17:99.55 W 5082.10 N 20 44 W COMPUTATION DATE: 03-0CT-89 PAGE ARCO ALASKA, INC. L3-1 LISBURNE PRUDHOE BAY/LISBURNE POOL NORTH SLOPEr ALASKA DATE OF SURVEY: 26-AUG-89 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZI.MUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 5529.37 5469.37 60 14 8[00.00 5578.75 5518.75 60 4[ 8200.00 5627.33 5567.33 6[ 9 8300.00 5675.98 5615.98 59 52 8400.00 57Z8.05 5668.05 57 56 8500.00 5780.75 5720.75 58 3Z 8600.00 5832.15 5772.15 59 37 8700.00 5882.35 5822.35 59 33 8800.00 5935.59 5875.59 55 50 8900.00 5993.02 5933.02 55 7 N 13 59 W 5144.56 N 13 42 W 5231.50 N 13 26 W 5318.88 N 14 35 W 5406.21 N 17 Z1 W 5491.53 N 16 57 W 5576.46 N 16 29 W 5662.21 N 16 34 W 5748.67 N 18 41 W 5833.21 N 19 21 W 5914.85 0.52 0.69 0.8¢ 3.76 0.46 0.97 0.58 2.14 3.96 1.07 4836.84 N 1820.68 W 5168.16 N 20 38 W 4921.29 N 18~.1.43 W 5254.52 N 20 31 W 5006.26 N 1861.92 W 5341.29 N 20 24 W 5091.16 N 1632.52 W 5428.05 N 20 18 W 5173.12 N 1906.30 W 5513.18 N 20 14 W 5254.29 N 19,31o46 W 5598.05 N 20 11 W 5336.47 N 1956.04 W 5683.66 N 20 8 W j 5419.42 N 1930.52 W 5769.98 N 20 4 W 5500.13 N 2005.88 W 5854.49 N 20 2 W 5577.40 N 2032.93 W 5936.34 N 20 2 W 9000.00 604.9.19 5989.19 56 40 9100.00 6103.39 6043.39 57 24 9200.00 6156.84 6096.84' 57 48 9300.00 6211.25 6151.25 55 58 94.00.00 6267.56 6207.56 55 57 9500.00 6323.00 6263.00 56 36 9600.00 6378.46 6318..46 56 9700.00 6434.17 6374.17 56 10 9800.00 6489.97 6429.97 56 13 9900.00 654.5.49 6485.49 56 32 N 18 53 W 5997.38 N 18 23 W 6081.26 N 18 20 W 6165.65 N 19 39 W 6249.37 N ZO 28 W 6331.69 N 20 45 W 6414.54 N 21 23 W 6497.31 N 21 49 W 6579.82 N 21 35 W 6662.26 N 21 3'9 W 6744.91 1.78 5655.56 N 2060.01 W 6019.06 N 20 I W 0.53 5735.20 N Z086.84. W 6103.07 N 20 0 W 0.86 5815.45 N 2113.36 W 6187.55 N 19 58 W 1.89 5894.86 N 2140.38 W 6271.41 N 19 57 W 0.83 5972.43 N 2158.90 W 6354.'06 N 19 58 W 0.40 6050.33 N 2198.18 W 6437.27 N 19 58 W 0.41 6127.99 N 2228.04 W 6520.47 N 19 59 W 0.50 6205.17 N 2258.69 W :5603.47 N 20 0 W 0.98 6282.28 N 2289.36 W 6686.42 N 20 1 W 1.10 6359.61 N 2319.98 W 6769.57 N 20 3 W 10000.00 6599.9.5 6539.95 57 9 10100.00 6655.17 6595.17 55 8 10200.00 6713.53 6653.53 54 22 10300.00 6771.47 6711.47 54 44 10400.00 6829.02 6769.02 55 14 10500.00 6885.42 6825.42 55 56 10600.00 6941.31 6881.31 56 6 10700.00 6997.14 6937.14 56 4 10800.00 7053.06 6993.06 55 57 10900.00 7109.17 7049.17 55 40 N 21 26 W 6828.24 N 21 5 W 6911.13 N 20 59 W 6991.91 N 20 58 W 7072.99 N 21 3 W 7154.35 N 21 22 W 7236.46 N ZO 53 W 7318.93 N 20 3 W 7401.54 N 19 36 W 7484.17 N 19 13 W 7566.72 0.57 3-38 0.63 0.46 I .16 0.43 0.81 0 0.56 0.66 6437.60 N 2350.83 W 6853.40 N 20 4 W 6515.29 N 2381.06 W 6936.74 N 20 5 W 6591.11 N 2410.12 W 7017.93 N 20 5 W 6667.21 N 2439.30 W 7039.43 N 20 6 W 6743.58 N 2468.55 W 7181.20 N 20 6 W 6820.55 N 2498.44 W 7263.76 N 20 7 W 6897.87 N 2528.44 W 7346.67 N 20 8 W 6975.61 N 2557.40 W 74.29.63 N 20 8 W 7053.62 It 2585.45 W 7512.53 N 20 8 W 7131.69 N 2612.94 W 7595.30 N 20 7 W 11000.00 7165.62 7105.62 55 47 11100.00 7221.65 7161.65 55 59 11200.00 7277.59 7217.59 56 5 11300.00 7333.25 7273.25 56 15 11400.00 7388.75 7328.75 56 25 11500.00 7444.01 7384.01 56 26 11600.00 7499.24 7439.24 56 23 11700.00 7554.84 7494.84 56 18 11800.00 7610.16 7550.16 56 31 11900.00 7665.22 7605.22 56 36 N 18 28 W 7649.10 N 18 21 W 7731.80 N 18 19 W 7814.56 N 18 20 W 7897.51 N 18 11 W 7980.57 N 18 5 W 8063.81 N 18 6 W 8147.06 N 18 10 W 8230.07 N 18 11 W 8313.26 N 18 1Z W 8396.62 0.49 0.11 0.21 0.13 0.37 0.28 0.61 0.64 0.41 0 7209.85 N 2639.49 W 7677.82 N Z,?, 6 W 7288.46 N 2665.59 W 7760.61 N 20 5 W 7367.15 N 2691.64 W 7843.46 N 20 4 W 7446.02 N 2717.75 W 7926.50 N 20 3 W 7525.01 N 2743.83 W 8009.64 N 20 2 W 7604.23 N 2769.74 W 8092.95 N 20 1 W 7633.47 N 2795.64 W 8176.26 N 20 0 W 7762.47 N 2821.46 W 8259.33 N 19 58 W 7841.63 N 2847.43 W 8342.60 N 19 57 W 7920.94 N 2873.48 W 8426.04 N 19 56 W COMPUTATION DATE: 03-0CT-89 PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 26-AUG-89' L3-1 LISBURNE KELLY BUSHING ELEVATION: 60 O0 FT PRUDHOE BAY/LISBURNE POOL - NORTH SLOPE, ALASKA ENGINEER: WARNER INTERPOLATED VALUES FOR EVEN 100 mEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VER'TICAL DOGLEG RECTANGULAR CQORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/~EST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 7720.04 7660.04 56 58 12100.00 7774.29 7714.29 57 19 12200.00 7828.72 7768.72 56 21 12300.00 78.84.77 7824.77 :55 39 12400.00 7941.09 7881.09 55 43 12500.00 7997.61 7937.61 55 34 12600.00 8054.12 7994.12 55 28 12700.00 8111.66 8051.66 54 23 12800.00 81,59.54 8109.54 54 53 12900.00 8227.04 8167.04 54 56 13000.00 8284.10 8224.10 55 18 13100.00 8341.45 8281.45 54 43 13200.00 8399.68 8339.68 53 55 13300.00 8459.37 8399.37 52 37 13400.00 8520.32 8460.32 52 5 13500.00 8582.20 8522.20 51 15 13600.00 8646.03 8586.03 49 22 13700.00 8711.19 8652.19 48 7 13800.00 8779.37 8719.37 47 40 13900.00 8846.72 8786.72 47 34 14000.00 8914.38 8854.38 47 13 14100.00 8982.46 8922.46 47 1 14200.00 9050.82 8990.82 46 50 14300.00 9119.81 9059.81 46 26 14375.00 9171.50 9111.50 46 26 N 18 12 W 8480.13 N 18 25 N 8564.01 N 18 43 W 8647.75 N 18 47 W 8730.40 N 18 44 W 8812.86 N 18 47 W 8895.20 N 19 4 W 8977.52 N 19 21 W 9059.11 N 19 36 W 9140.42 N 19 29 N 9222.00 N 19 47 W 9303.87 N 19 45 W 9385.52 N 19 32 W 9466.57 N 19 27 W 9546.56 N 19 40 W 9625.60 N 19 46 W 9703.90 N 18 2 W 9780.69 N 18 14 W 9855.58 N 18 10 W 9929.55 N 17 47 W 10003.37 N 17 35 W 10076.94 N 17 1 W 10150.13 N 16 5-6 W 10223.03 N 16 42 W 10295.84 N 16 42 W 10350.16 0.53 0.49 1 .29 0.31 0.62 O.1B 0.74 0.44 0.77 0 · 42 0.86 0.80 1.88 1.12 0.48 1.63 2.0Z 0.54 0.25 0.33 0.68 0.62 0.42 0.00 0.00 8000.39 N 2899.59 W 8509.63 N 19 55 W 8080.15 N 2925.95 ;4 8593.61 N 19 54 W 8159.69 N 2952.62 W 8677.47 N 19 54 W 8238.08 N 2979.31 ~4 ~760.26 N 19 53 W 8316.33 N 3005.84 W 8842.88 N 1'9 52 W .... 8394.45 N 3032.35 W 8925.35 N 19 52 1 ~) 8472.50 N 3059.08 W 9007.8,4 N 19 51 k -- 8549.76 N '30,~5.92 W 90~9.63 N 19 51 W 8626.63 N 3113.14 W 9171.17 N 19 51 W 8703.74 N 3140.48 W 9252.98 N 19 50 W 8781.09 N 3168.05 W 9335.10 N 19 50 W 8858.19 N 3195.74 W 9417.02 N 19 50 W 8934.76 N 3223.07 W 9498.32 N 19 50 W 9010.36 N 3249.90 W 9578.54 N 19 50 W 9085.05 N 3276.49 W 9657.82 N 19 50 W 9158.98 N 3303.05 W 9736.38 N 19 50 W 9231.74 N 3328.11 W 9813.33 N 19 49 W 9303.07 N 3351.23 W 9888.27 N 19 49 W 9373.45 N 3374.36 W 9962.32 N 19 48 W 9443.75 N 3397.17 ~410036.19 N 19 47 W 9513.90 N 3419.57 W10109.79 N 19 46 W 9583.84 N 3441.32 W101~2.96 N 19 45 W 9653.67 N 3462.55 W10255.86 N 19 44 W 9723.36 N 3483.5% W10328.54 N 19 43 W 9775.41 N 3499.15 W10382.81 N 19 42 W COMPUTATION DATE: 03-DCT-89 ARCO ALASKA, INC. L3-1 LISBURNE PRUOHOE BAY/LISBURNE POOL NORTH SLOPE, ALASKA DATE OF SURVEY: 26-AUG-89 KELLY 5USHING ELEVATION: 60.00 FT ENGINEER: WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M'IN DEG MIN 0.00 0.00 -60.00 0 0 1000.00 995.15 935.15 12 47 2000.00 1911.05 1851.05 32 19 3000.00 2657.33 2597.33 49 20 4000.00 3255.35 3195.35 52 16 5000.00 3839.27 3779.27 54 22 6000°00 4424.94 4364.94 54 40 7000.00 5003.39 4943.39 55 28 8000.00 5529.37 5469.37 60 14 9000.00 6049.19 5989.19 56 40 lOOOO.O0 6599.95 6539.95 57 9 11000.00 7165.62 7105.62 55 47 12000.00 7720.04 7660.04 56 58 13000.00 8284.10 8224.10 55 18 14000.00 8914.38 8854.38 47 13 14375.00 9171.50 9111.50 46 26 VERTIC=~L DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN N 0 0 E 0.00 N 7 33 W 60.12 N 15 33 W 448.76 N 14 39 W 1109.32 N 24 43 W 1:~06.74 N 30 33 W 2691.76 N 22 1 W 3480.'13 N 16 1 W 4294.57 N 13 59 W 5144.56 N 18 53 W 5997.38 0.00 3.04 3.31 3.11 0.51 1.35 0.62 0.52 1 0.00 N 0.00 E 0.00 N 0 0 E 58.83 N 12.74 W 60.19 N 12 13 W 439.22 N 94.91 W 449.36 ' N 1Z 12 W 1066.18 N 306.83 W '1109.45 N 16 3 W 1822.59 N 564.39 W 1907.97 N 17 1Z W 2526.74 N 967.42 W Z705.61 N 20 57 W ~ 3239-51 N 1351.5Z W 3510.13 N 22 39 W ~) 4015.25 N 1602.77 W 4323.32 N 21 46 W ~ 4836.84 N 1820.68 W 5168.16 N ZO 38 W 5655.55 N 2060.01 W 6019.06 N 20 1 W N Z1 26 W 682:8.24 N 18 28 W 7649.10 N 18 12 W 8480.13 N 19 4'7 W 9303.87 N 17 35 W 10076.94 N 16 42 W 10350.16 0.57 0.49 0.53 0°86 0 0.00 6437.60 N 2350.83 W 6853.40 N 20 4 W 7209.85 N 2639.49 W 7677.82 N 2.0 6 W 8000.39 N 2899.59 W 8509.63 N 19 55 W 8781.09 N 3168.05 W 9335.10 N 19 50 W 9513.90 N 3419.57 W10109.79 N 19 46 W 9775.41 N 3499.15 W10382.81 N 19 42 W COMPUTA'TION DATE: 03-~CT-89 PA.~E 6 ARCO ALASKA, INC. DATE OF SURVEY: 26-AUG-SO 13-1 LISBURNE KELLY BUSHING E'LEVATION: 60.00 FT PRUDHOE BAY/LISBURN'E POOL NORTH SLOPE, ALASKA ENGINEER: WARNER INTERPOLATED VALU:S FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -60.00 0 0 N 0 0 E 60.00 60.00 0.00 0 9 N 3 40 W 160.00 150.00 100.00 0 7 S 77 17 E 260.00 260.00 200.00 0 35 S 53 52 W 360.00 360.00 300.00 0 27 S 55 0 W 460.01 460.00 400.00 0 36 S 58 38 W 560.02 560.00 500.00 1 50 N 43 12 W 660.29 660.00 600.00 5 18 N 14 5 W 760.91 760.00 700.00 7 55 N 8 31 W 862.14 860.00 800.00 9 46 N 6 59 W 964.00 960.00 900.00 12 6 N 7 19 W 1066.76 1060.00 1000.00 14 36 N 7 36 W 1170.55 1160.00 1100.00 16 12 N 9 8 W 1275.16 1260.00 1200.00 18 10 N 11 30 W 1381.36 1360.00 1300.00 21 19 N 13 10 W 1489.65 1460.00 1400.00 23 34 N 12 39 W 159'9.67 1560.00 1500.00 25 42 N I1 50 W 1711.35 1660.00 1600.00 27 4 N 12 O W 1824.71 1760.00 1700.00 29 7 N 13 2 W 1940.13 1860.00 1800.00 30 52 N 14 54 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEmARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST. AZIMUTH F~ET DEG/IOO FEET FEET FEET DEG MIN 2058.47 1960.00 1900.00 34 26 2183.29 2060.00 2000.00 38 33 2314.12 2160.00 2100.00 41 14 2447.03 2260.00 2200.00 40 59 2580.06 2360.00 2300.00 42 36 2717.76 2460.00 2400.00 43 7 2856.62 2560.00 2500.00 45 24 3004.15 2660.00 2600.00 49 27 3165.63 2760.00 2700.00 53 26 3338.28 2860.00 2800.00 55 30 0.00 0.00 0.00 N 0.00 E 0.03 2.33 0.03 N 0.00 E 0.01 0.24 0.04 N 0.08 E -0.14 0.82 0.17 S 0.10 W -0.36 1.07 0.55 S 0.66 W -0.73 0.28 1.19 S 1.60 W -0.39 7.36 1.16 S 2.76 W 6.65 1.46 5.49 N 5.18 W 17.72 2.94 16.38 N 7.31 W 33.29 3.44 31.95 N 9.35 W 3511.4'9 2960.00 2900.00 54 5 3679.14 3060.00 3000.00 53 29 3846.41 3160.00 3100.00 51 47 4007.58 3260.00 3200.00 52 22 4174.08 3360.00 3300.00 53 28 4345.07 3460.00 3400.00 54 32 4518.70 3560.00 3500.00 54 36 4691.23 3660.00 3600.00 54 36 4863.47 3760.00 3700.00 54 31 5035.51 3860.00 3900.00 54 1~ 52.43 1.75 51.14 N 75.84 2.56 74.56 N 103.43 1.31 102.05 N 133.98 2.74 132.23 N 169.66 2.83 167.07 N 211.16 2.02 207.54 N 256.94 1.85 252.35 N 306.59 1.45 301.03 N 359.88 1.75 353.13 N 417.49 2.01 409.05 N N 15 58 W 480.74 N 18 36 W 555.34 N 21 16 W 639.33 N Z1 58 W 726.30 N 21 4 W 813.,43 N 17 37 W 907.79 N 16 10 W 1004.08 N 14 36 W 1112.49 N 13 24 W 1239.20 N 14 57 W 1379.89 N 20 56 W 1521.10 N 22 16 W 1654.78 N 23 9 W 1787.57 N 24 57 W 1912.65 N 27 19 W 2043.21 N 30 Z W 2177.77 N 31 13 W 2314.34 N 30 51 W 2449.55 N 30 41 W 2584.54 N 30 27 W 2719.56 4.34 3.33 1.02 0.56 3.15 2.15 2.65 3.30 1.27 0.87 2.47 2.35 0.91 3.24 1.92 0.74. 0.54 0.20 0.05 0.24 0.00 N 0 0 E 0.03 N 5 13 E 0.09 N 66 11 E 0.19 S 29 28 W 0.86 S 50 11 W 1.99 S 53 30 W 2.99 S 67 16 w 7.54 N 43 21 W' ~, 17.93 N 24 3 W 33.29 N 16 18 W 11.73 W 52.47 N 12 55 W 14.81 W 76.01 N 11 14 W 18.83 W 103.78 N 10 27 W 24.25 W 134.44 N lO 24 W 32.12 W 170.13 N 10 53 W ~+1.45 W Zli.64 N 11 18 W 51.10 W 257.47 N 11 27 W 61.28 W 307.21 N 11 30 W 72.78 W 360.55 N 11 39 W 86.66 W 418.13 N 11 58 W 470.00 N 103.59 W 481.28 N 12 26 W 541.41 N 125.31 W 555.72 N 13 2 W 620.49 N 154.59 W 639.46 N 13 59 W 701.83 N 186.96 W 726.31 N 14 55 W 783.29 N 219.51 W 813.47 N 15 39 W 872.45 N 251.25 W 907.91 N 16 4 W 964.72 N 278.88 W 1004.22 N 16 7 W 1069.25 N 307.62 W 1112.62 N 16 3 W 1192.30 N 338.00 W 1239.29 N 15 50 W ~ 1328.75 N 372.38 W 1379.95 N 15 39 W 1463.6~. N 414.50 W 1521.21 h 15 49 W 1588.68 N 464.22 W 1655.11 N 16 17 W 1712.03 N 516.71 W 1788.30 N 15 ~+B W 1828.04 N 566.85 W 1913.91 N 17 14 W 194'7.27 N 626.05 W 3045.43 N 17 49 W 2068.39 N 693.59 W 2131.58 N 18 32 W 2190.11 N 766.60 W 2320.40 N lg 17 W 2310.56 N 839.11 W 2458.21 N 19 58 W 2431.11 N 910.75 W 2596.11 N 20 32 W 2551.59 N 982.05 W 2734.05 N 21 3 W COMPUTATION DATE: 03-0CT-89 PAGE 7 ARCO ALASKA, INC. L3-1 LISBURNE PRUDHOE BAY/LISBURNE POOL NORTH SLOPE, ALASKA ., DATE OF SURVEY: 26-AUG-89 KELLY :BUSHING ELEVATZON: 60.00 FT ENGINEER: WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SE.* OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST gIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5206.69 3960.00 3900.00 54 27 5376.72 4060.00 4000.00 53 45 5544.56 4160.00 4100.00 53 7 5713.08 4260.00 4200.00 54 51 5888.36 4360.00 4300.00 54 48 6061.08 446D.00 4400.00 54 54 6235.50 4560.00 4500.00 55 6409.28 4660.00 4600.00 54 43 6580.90 4760.00 4700.00 54 10 6751.19 4860.00 4800.00 54 4 N 3O 6 W 2853.68 N 30 5 W 2986.56 N 29 45 W 3116.88 N 26 58 W 3248.73 N 24 4.1 W 3390.21 N :)1 30 W 3529.81 N 18 0 W 3672.28 N 17 48 W 3814.24 N 17 30 W 3953.58 N 17 6 W 4091.32 0..39 0.73 0.48 2.01 1.69 1.3 9 0.65 0.31 0.21 0.79 2671.56 N 1052.13 W 2871.21m' N 21 30 W 2790.57 N 1121.00 W 3007.32 N 21 53 W ,2907.37 N 1188.29 W 3140.83 N 22 14 W 3026.35 N 1253.36 W 3275.62 N 22 30 W 3156.00 N 1315.87 W 3419.34 N 22 38 W '-,~ 3285.95 N 1370.09 W 3560.14 N 22 38 W 3420.66 N 1417.67 W 3702.80 N 22 31 W 3555.90 N 1461.35 W 3844.48 N 22 ZO W 3688.83 N 1503.56 W 3983.49 N 22 11 W 3820.43 N 154.4.57 W 4120.85 N 22 1 W 6923.79 4960.00 4900.00 55 6 7100.21 5060.00 5000.DO 55 49 7281.54 5160.00 5100.00 57 7 7468.99 5260.00 5200.00 58 24 7661.95 5360.00 5300.00 59 18 7860.90 5460.00 5400.00 60 8 8061.85 5560.00 5,500.00 60 $267.81 5660.00 5600.00 60 40 8460.43 5760.00 5700.00 58 15 8655.33 5860.00 5800.00 59 55 N 16 28 W 4231.::93 N 15 46 W 4377.26 N 15 38 W 4528.50 N 14 51 W 4687.04 N 14 16 W 4852.10 N 14 5 W 5024.02 N 13 46 W 5198.29 N 13 4>3 W 5373.27 N 17 11 W 5542.79 N 16 27 W 5710.00 0.90 0.74 0.55 0.70 0.71 0.61 0.54 2.60 0.76 0.91 3955.08 N 1535.28 W 4.260.96 N 21 51 W 4094.79 N 1625.36 W 4.405.58 N 21 39 W 4240.39 N 1666.33 W 4556.04 N 21 27 W 4393.36 N 1707.98 W 4713.68 N 21 15 W 6553.15 N 1749.36 W 4877.65 N 21 I W ~+719.92 N 1791.29 W 5048.40 N 20 47 W z~889.01 N 1833.55 W 5221.53 N ZO 33 W 5064.06 N 1875.71 W 5400.27 N 20 19 W 5222.09 N 1921.57 W 5564.41 N ZO 12 W 5382.32 N 1969.58 W 5731.37 N 20 6 W 8842.66 5960.00 5900.00 54 56 9019.77 6060.00 6000.00 57 0 9205.96 6160.00 6100.00 57 46 9386.50 6260.00 6200.00 55 51 9567.00 6360.00 6300.00 56 11 9746.32 6460.00 6400.00 56 3 9926,42 6560.00 6500.00 56 49 10108.50 6660.00 6600.00 54 51 10280.08 6760.00 6700.00 54 41 10454.73 6860.00 6800.00 55 42 N 19 18 W 5868.10 N 18 4? W 6013.89 N 18 21 W 6170.70 N 20 25 W 6320.56 N 21 10 W 6470.12 N 21 42 W 6618.01 N 21 33 W 6766.84 N 21 3 W 6918.08 N ZO 59 W 7056.80 N 2.1 15 W 7199.22 1.48 1.10 1.0~ 0.84 1.28 0.35 1.03 3.40 0.69 0.73 5533.18 N 2017.35 W 5899.46 N 20 2 W 5671.22 N 2065.36 W 6035.60 N 20 I W 5820.25 N 2114.95 W 6192.60 N 19 58 W 5961.95 N 2164.99 W 6342.87 N 19 57 W 6102.51 N 2218.11 W 6493.13 N 19 58 W 6240.88 N 2272.96 W 6641.91 N 20 1 W ' 6380.14 N 2328.12 W 6791.63 N 20 3 W } 6521.81 .N 23~3.58 W 6943.73 N 20 5 W 6652.01 N 2433.47 W 7083.15 N 20 6 W 6785.66 N 2484.81 W 7226.31 N ZO 7 W 10633.55 6960.00 6900.00 56 6 10812.43 7060.00 7000.00 55 57 10990.00 7160.00 7100.00 55 45 11168.48 7260.00 77-00.00 56 0 11348.15 7360.00 7300.00 56 17 11528.92 7460.00 7400.00 56 27 11709.31 7560.00 7500.00 56 19 11890.54 7660.00 7600.00 56 34 12073.56 7760.00 7700.00 57 12 12256.01 7860.00 7800.00 55 50 N 20 35 W 7346.66 N 19 33 W 7494.45 N 18 31 W 7640.84 N 18 19 W 7788.45 N 18 17 W 7937.49 N 18 6 W 8087.87 N 18 10 W 8237.91 N 18 1Z W 8388.74 N 18 21 W 8541.81 N 18 50 W 8694.11 0.84 0.54 0.60 0.41 0.21 0.26 0.Sg 0.16 0 ,,49 oi,eo 6923.92 N 2538.31 W 7374.53 N ?0 8 W 7063.33 N 2588.91 W 7522.84 N 2.0 8 W 7202..01 N 2636.87 W 7669.56 N 2.0 7 W 7342.32 N 2683.43 W 7817.32 N 20 5 W 7484.03 N 3730.33 W 79,56.52 N 20 3 W 7627-13 N 2777.22 W 8117.02 N 20 0 W 7769,,'84 N 2823.88 W 8267.09 h 19 58 W 7913.44 N 2871.02 W 8418.15 N 19 56 W 8059,04 N 2918.94 W 8571.37 N 19 55 W 9203:66 N 2967.60 W 8723.91 N 19 53 W COMPUTATION DATE: 03-0CT-89 PAGE ARCO ALASKA, INC. L3-1 LISBURNE PRUDHOE BAY/LISBURNE POOL NORTH SLOPE, ALASKA DATE OF SURVEY: 26-AUG-89. KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: WARNER INTERPOLATES VALUES FOR EVEN 100 FEET OF SUB-SE~ DEPTH TRUE SUE-SEA COURSE VERTIC&L DOGLEG R?CTANGUL~R COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/S3UTH EHST/WEST DIST. AZIMUTH DEPTH DEPTH OEPTH DEG MIN 12433.49 7960.00 7900.00 55 37 12610.36 9060.00 8000.00 55 22 12783.37 8160.00 BtO0.O0 54 50 12957.52 3250.00 8200.00 55 17 13132.02 8360.00 8300.00 54 30 13301.03 8460.00 8400.00 52 38 13464.32 8560.00 8500.00 51 41 13621.41 8660.00 8600.00 48 58 13771.26 8760.00 8700.00 47 41 13919.68 BBEO.O0 BBO0.O0 47 31 14067o01 8960.00 8900.00 47 5 14213.43 9060.00 9000.00 46 47 14358o31 9160.00 9100.00 46 26 14375.00,:~9171.50~ 9111.50 46 26 DEG MIN FEET DEG/IO0 N 18 45 W 8840.45 N 19 5 W 8986.03 N 19 35 W 9125.84 N 19 39 W 9269.00 N 19 42 W 9~+11.54 N 19 27 W 9547.37 N 19 48 W 9676.06 N 17 51 W 9796.89 N 18 11 W 9908°34 N 17 45 W IO017.BB N 17 10 W 10125.98 N 16 54 W 10232.88 N 16 42 W 10338.07 N 16 4Z W 10350.16 0.2 '9 0.98 1.10 1.23 0.54 1.17 0.90 2.24 0 0.28 0.6Z 0.85 0.00 0.00 FEET FEET FEET DE5 MIN 8342.51 N 3014.72 ;4:9970.51 N 19 52 W 8480.57 N .3061.86 W 9016.38 N 19 51 W 3613.81 N 3108.55 W 91.57.55 N 19 51 W 8748.17 N 3156.22 W 9300.11 N 19 50 W 8882.7]' N 3204.53 W 9443.13 N 19 50 W 9011.13 N 3250.18 W 95'79.36 N 19 50 W ', 9132.70 N 3293.57 W 9708.44 N 19 50 W ) 9247.19 N 3333.07 W 9829.54 N 19 49 W 9353.27 N 3367.73 W 9941.09 N 19 48 W 9457.58 N 3401.59 W10050.71 N 19 47 W 9560.75 N 3434.22 W10158.82 N 19 45 W 9663.05 N 3465.40 W10Z65.65 N 19 44 W 9763.83 N 3495.68 W10370.74 N 19 42 W 9775.41t, N 3499.15v'~lO382.B1 N 19 42 W COMPUTATION DATE: 03-0CT-~9 PA~E 9 ' ARCO ALASKA, INC. L3-1 LISBURNE PRUDHOE BAY/LISBURNE POOL NORTH SLDPE~ ALASKA DATE OF SURVEY: 26-AUG-89 KELLY BUSHING E.LEVATION: 60.00 FT ENGINEER: WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 287' FNL & 550' FWL, SEC22 TI1N R1SE MARKER MEASURED 'DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTHJSOUTH EAST/WEST 13 3/8" CASING TOP 7" LINER 9 5/8" CASING TOP WAHOO ZONE 7 TOP WAHOO ZONE 6 TOP WAHOO ZONE 5 TOP WAHOO ZONE 4 GCT LAST READING P'BTD BOTTOM 7" LINER TD 5264.00 3993.27 3933.27 2711.95 N 13304.00 8461.81 8401.81 9013.36 N 13590.00 8639.51 8579.5t 9224.53 N 13687.00 8703.53 8643.53 9293.87 N 13812.00 8787.45 8727.45 9381.87 N 13997.00 8912.34 8852.34 9511.B0 N 14120.00 BOg6.11 8936.11 9597.82 N 14242.60 9080.25 9020.25 9683.52 N 14326.00 9137.73 9077.73 9741.40 N 14368.00 9166.68 9106.68 9770.55 N 14375.00 9171.50 9111.50 9775.41 N 1075.48 W 3250.96 W 3325.79 W 3348.20 W 3377.13 W 341B.91 W 344 5.59 W 3471.59 W 3488.95 W 3497.69 W 3499.15 W COMPUTATION DATE: 03-0CT-89 PAGE ARCO ALASKA, INC. L3-1 LISBURNE PRUDHOE BAY/LISBURNE POOL NORTH SLOPE, ALASKA DATE OF SURVEY: Z6-AUG-S9 ' KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: WARNER **:**:*****"~** STRAT IGRAPHIC SUMMARY *:******.,*:**** SURFACE LOCATION : 287' FNL & 550' mWL, SEC22 T11N R15E MARKER MEASURED DEPTH BELOW KB TVO F~OM KE~ SU~-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE PBTD TD 13687.00 8703.53 8643.53 13812.00 8787.45 8727.45 13997.00 8912.34 8852.34 1¢120.00 8996.11 8936.11 14326.00 9137.73 9077.73 14375.00 9171.50 9111.50 9293.87 N 9'381.87 N 9511.80 N 9597.82 N 9741.40 N 9775.41 N 3348.20 W 3377.13 W 3418.91 W 3445.59 W 3488.95 W 3499.15 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 14375.00 9171.50 9111.50 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10382.81 N 1'9 42. W SEHLUMBEROER D ]; RECT ]; ONRI_ SURVEY COMPANY ARCO ALASKA, INC. NELL L3- i L I SBURNE FIELD PRUDHOE BAY/LISBURNE COUNTRY USA RUN ONE DATE LOOOED 28 - AUG - 89 REFERENCE ?9494 POOL WELL ' ( 287 ' LISBUR~E L3-1 FNL, 550' FWL, SEC 22, Tl lN, R15E, UM) ......... ~iZONTAL PROJECTION NORTH ! 2000 REF ! 0000 SCALE : !/2000 73494 : . ~., ~ - .... "": ....! "~'[ '...~ . .' i. i'"i'";- ::::::::::::::::::::::::::::::::: ~: ..... ~...'~.-..~ ............ i .... ~.--? ...... ? ............ ~ .... , ......... :~: ~, ........ ~-...~....~-.~ .... ~ '.; L..h..;..,..~ '.. --?.-.y...;-~--.-h..;--";-?"i"'I.'"'~"'rlZ'lT"~ll'Z"'i""~'.'?..l....i ..;...;...L.L~; 8OOO 600O 4000 2000 -2000 SOU~H -4000 -BO00 -6000 -4OOO -2000 £000 4000 6000 8000 EAST WELL ' '(287' LiSBURNE L3-1 FNL, 550' FWL, SEC 22, TllN, R15E, UM) V ~-'"T I CAL PROJECT I ON -2000 0 0 2000 4000 6000 .., ~-i ~.~ !..-~ i : L...Z.-.L-..' ........ - ..L---i- -~ .... ;...;... ;..¥...:,..-~..-~ .... ~.-'-;--'~'"'T'i"; ~- .:...:....~...~. ........ 8000 10000 12000 4000 B4S. PROJECT ION ON VERT I CAi- PLANE 945, - 165. SCALEO 1N VER'f ICAL BEP'fHS HORIZ SCALE = 1/2000 IN/FT ' -~ STATE OF ALASKA AI_~ OILAND GAS CONSERVATION COMM,,~ION ~" '-:~ ~ ~ ~ ~ ~, REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Stimulate Plugging __ Perforate __ Alter casing ~ Repair well Pull tubing _ Other X Completion 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~X ARCO Alaska. Inc. Exploratory _ 60' RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Prudhoe Bay Unit/Lisburne 4. Location of well at surface 8. Well number 287' FNL, 55O' FWL, Sec. 22, T11N, R15E, UM I,~-1 At top of productive interval 9. Permit number/approval number 1553' FNL, 2482' FWL, Sec. 9, T11N, R15E, UM 8~-75/~l-785 At effective depth 10. APl number 1106' FNL, 2341' FWL, Sec. 9, T11N, R15E, UM 50-029-2195~ At total depth 11. Field/Pool Prudhoe Bay Field 1072' FNL, 2331' FWL, Sec. 9, T11N, R15E, UM Lisburne Oil Pool 12. Present well condition summary Total Depth: measured 14375' feet Plugs (measured) None true vertical 91 72' feet Effective depth: measured 14326' feet Junk (measured) None true vertical 91 38' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 2 0" 2150# Poleset 1 1 5' 1 1 5' Surface 5226' 1 3-3/8" 3500 sx AS III & 5264' 3993' 500 sx Class G - Top job w/175 sx AS I Intermediate 13555' 9-5/8" 500 sx SS II 13590' 8640' Liner 1064' 7" 184 sx ARC (Class G) 13304'-14368' 8462'-9167' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) ~ ..~ .~;, 4-1/2", L-80, tbg w/tail @ 13579' Packers and SSSV (type and measured depth) 'I-} ~ (~ *,~ ;;' Baker 'DB' pkr @ 13244', 'HRQ' SSSV @ 2304' 13. Stimulation or cement squeeze summary ,~;,~.!¢~ ~ [~ ~/~. ~:1~ ~0~~ ~' I ~'1''~ ~;~1~';" ~':;~ ~ Intervals treated (measured) 13945'-13950' Treatment description including volumes used and final pressure 20 bbl 15% HCI & 93 sx Class G 14. Re_oresentative Daily Average Production or Iniection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments *Completion Well History 16. Status of well classification as: Copies of Logs and Surveys run X Water Injector ~ Daily Report of Well Operations X* Oil X Gas Suspended Service , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed l~ ~/)r~/,.~ .~,/,,,~,~..A~ Title Drillin~l Analyst Date Fnrm 1 {3-z~}a. R~.,~ ~3~';;/17/R_q _~l II:tl~,11T I1~1 ~11131 ARCO Oil and Gas Company Well History - Initial Report- Daily IIIstructions: Prepare and submit the "Initial ReDort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field ,C .... ,Y' pari~]%c~'~c}'~°U~%o P E Istate AK IL .... or U~)L: 34631 L3-1 ITitle COMPLETE API: 50-029-21959 lWell no. LISBURNE Auth. or W.O. n°-L092-A 3 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 10/20/89 ( TD: 0 PB:14326 SUPV:LP 10/21/89 ( TD: 0 PB:14326 SUPV:LP 10/22/89 ( TD: 0 PB:14326 SUPV:LP 10/23/89 ( TD: 0 PB:14326 SUPV:LP 10/24/89 ( TD: 0 PB:14326 SUPV:LP The above is correct c For form~,Dreparetion and distribution IDate 10/19/85 IHour 0830 Prior status , a W.O. Complete record for each day reported NABORS 1ES POOH W/ E-LINE 7"@14368' MW: 0.0 NaCl ACCEPT RIG @ 0830 HRS ON 10/19/89. ND TREE. NU BOPS. TEST 9-5/8" PO TO 3800 PSI. GOOD. PULL BPV & DUMMY HNGR. SET TEST PLUG & TEST BOPS, CHOKE & VALVES. GOOD. PULL TEST PLUG & INSTALL BUSHING. RIH W/ 3-1/2" DP & DISP 600' DIESEL CAP TO 9.2 BRINE. TEST 9-5/8" X 7" TO 3500 PSI F/ 30 MIN. GOOD. RU E-LINE. RUN GR/JB TO 14,060'. POOH & PU EZSV. RIH & SET @ 13,980'. POOH. DAILY:S92,241 CUM:$3,336,307 ETD:S3,336,307 RFC:S100 PUMP CMT SQUEEZE 7"@14368' MW: 0.0 NeC1 SET EZSV @ 13980'. PERF 13945'-13950' W/ 30 DEG, 6 SPF SUPER OMNI-CONE GUN. POOH. RD E-LINE. EST INJ RATE OF 1 BPM @ 1150 PSI. PU 24 JTS 2-7/8 TBG WS. PU 3-1/2 DP. RU BJ TITAN & TEST LINES. PUMP 20 BBLS HCL ACID, FLUSH W/ 110 BBLS BRINE. EST INJ RATE OF 1.3 BPM @ 1150 PSI AFTER ACID. BATCH CLASS G CMT & PUMP 18 3/4 BBLS W/ AU-198 TRACER. DAILY:S61,465 CUM:$3,397,772 ETD:S3,397,772 RFC:S100 DRILLING CMT 7"@14368' MW: 0.0 NaC1 FIN PUMP 5 BBL SPACER,& 18 3/4 BBLS CLASS G, 91BBLS 9.2 BRINE. HESITATION SQUEEZE 5 BBLS AWAY. HOLD SI PRS @ 1150 PSI. CUT & SLIP DRL LINE. POOH.PU 18 4-3/4" DC'S W/ 6" BIT & RIH. WASH STRINGERS F/ 13447'-13539'. DRILL HD CMT F/ 13553 13834'. DAILY:S59,144 CUM:$3,456,916 ETD:S3,456,916 RFC:S100 RIH W/ E-LINE 7"@14368' MW: 0.0 NaC1 DRILL CMT TO 13988'. CIRC HOLE CLEAN. TEST SQUEEZE PERFS TO 1200 F/ 40 MIN. GOOD. DRILL CMT F/ 13998' TO 13988'. TAG EZSV. DRILL ON SAME. EZSV DROPPED DOWN HOLE. PUSH EZSV TO BTM @ 14337'. REVERSE HEC SWEEP @ 60 SPM, 1000 PSI. POOH & STRAP PIPE. RU SCHLUMBERGER. RIH W/ CET/CBT/GR/CCL. DAILY:S37,191 CUM~$3,494,107 ETD:S3,494,107 RFC:S100 POOH W/ LOGGING TOOLS 7"@14368' MW: 0.0 NaC1 POOH W/ SCHLUM TO CHANGE OUT CRT/CBT/GR. RIH AND LOG F/ 14289' TO 13296'. RD E-LINE. C/O TOP RAMS TO 4-1/2" & TEST TO 5K PSI. GOOD. MU 4-1/2" TAIL ASSY W/ 9-5/8" BAKER 'DB' PKR & RIH ON DP. RIH TO 13230' & SET PKR. GOOD SETTING INDICATIONS. SHEAR OFF PKR. POOH & LDDP. DAILY:S54,196 CUM:$3,548,303 ETD:S3,548,303 EFC:$100 see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supt. AR3B-459-1-D ]Number all daily well history forms consecutively ~'~,i?/',j:;[.;~,','-'~a~ they are prepared for each well, I iPage no, ARCO Oh and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequenHy than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ,IC°unty or Parish I State ARCO ALASKA INC. J NORTH SLOPE AK Field ILease or Unit LISBURNE I L3-1 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. NABORS ~ES lWell no. 10/25/89 ( TD: 0 PB:14326 SUPV:LP The above'"i~ correct Signatu~,~. ~ For form pr~paratlon and distribution DISP TO SEA WATER 7"@14368' MW: 0.0 FSW POOH & LDDP. REMOVE W-RING. RIG FLOOR TO RUN 4-1/2" 2OMP. RIH W/ C'3MP. STING INTO PKR & PHS TO 500 PSI TO VERIFY. MU TBG HNGR & SPACE OUT. MU CNTL LINES AND TEST TO 500", PS!. GOOD. DISP WELL TO INHIB SEA WATER. ('HRQ' SSSV @ 2304', BAKER 'DB' ?KR @ 13244', TT @ 13579'.) DAILY:S302,178 CUM:$3,850,481 ETD:S3,850,481EFC:$100 Title /"~ n see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Supt. AR3B-459-2-B Humber all daily well history forms consecutively ..~J ,~ they are prepared, ..... h well. Page no. ARCO (Jil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable fength of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporting the 6ntire operation if soace is available. Accounting cost center code District [State ARCO ALASKA INC. / AK / County or Parish NORTH SLOPE Field Lease or Unit LISBURNE ADL: 34631 L3-1 Auth. or W.O. no. Title AL0923 COMPLETE API: 50-029-21959 Operator AR.Co. W,I. ARCO 40. 0000 Well no. Spudded or W.O. begun ACCEPT Date Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our Prior status if a W,O. 0830 10/19/85 Date and depth as of 8:00 a.m. 10/26/89 ( TD: 0 PB:14326 SUPV:LP Complete record for each day reported NABORS 1ES RIG RELEASED 7"@14368' MW: 0.0 FSW CONT TO DISP WELL TO INHIB SEA WATER. U-TUBE DIESEL TO FREEZE PROT ANN & TBG TO 2200' MD. TEST TBG TO 3000 PSI THEN 3500 PSI F/ 30 MIN. GOOD. BLEED TO 1500 PSI & PRESS 9-5/8" X 4-1/2" ANN TO 3500 PSI F/ 30 MIN. GOOD. BLEED TBG & ANN. LD LNDG JT. SET BPV & RD FLOOR. C/O TOP RAMS TO 3-1/2". ND BOPS & NU THA & MASTER VALVE. TEST CNTL LINES TO 5000 PSI. GOOD. REST OF TREE TO BE NU AFTER RIG MOVE. RELEASE RIG @ 1900 HRS ON 10/25/89. DAILY:S62,049 CUM:$3,912,530 ETD:S3,912,530 EFC:$100 Old TD New TD Released rig PB Depth K nd of r g Classifications (oil, gas, etc.) Type completion (single, dual. etc.) Producing method Official reservoir name(s) Potential test data ,, Well no. Date Reservoir Producing Interval Oil or gasTest time Production O{I on test Gas per day Pump size, SPM X length Choke size T,P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct / \~\\ % ~ ~ '7_ Drilling Supt. For form preparation and distribution, seeP .... d .... M .... I, Section 10, ~ ~ t~ ~:~ ~j~' il; ;~'"~ Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well, jPage no, Division of AtlantlcRIchfleldCompany i STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown ~ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ RKB 60' feet ARCO Alaska, I nc, Exploratory__ 3. Address Stratigraphic __ 7. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit/Lisburne 4. Location of well at surface 8. Well number 287' FNL, 549' FWL, 5ec.22, T11N, R15E, UM L:~-I At top of productive interval 9. Permit number 1470' FNL, 1970' FEL, Sec. 9, TllN, R15E, UM (approx) 89-75 At effective depth 10. APl number 884' FNL, 2339' FEL, Sec. 9, T11N, R15E, UM (approx) 50-029-21959 At total depth 11. Field/Pool 847' FNL, 2352' FEL, Sec. 9, T11N, R15E, UM (approx) Lisburne Oil Pool 12. Present well condition summary Total depth: measured 14375'MD feet Plugs(measured) None true vertical 9176'TVD feet 14326'MD None Effective depth: measured 9145 'TVD feet ,Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural 80 ' 20" 2150# Pol eset 115 ' MD 115' TVD Conductor 5226' 13-3/8" 3500 sx AS Ill & 5264'MD 4000'TVD Sudace 500 sx Class G - Top job w/175 sx AS I Intermediate 13555' 9-5/8" 500 sx SS I I 13590 'MD 8684 ' TVD Production 1064' 7" 184 sx ARC (Class G) 13304'-14368'MD 8507'-9172'TVD Liner Perforation depth: measured None true vertical None ECE VED 0 Tubing (size, grade, and measured depth) '- '-'- ' Packers and SSSV (type and measured depth) ~one 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ Well Hi story 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal was verbally approved Oil .__~ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed l 'I, ~ ~,~ Title Drilling Analyst Date / FOR COMMISSION USE ONLY Conditions of aPl~val: Notify Commission so representative may witness I Approval No. Plug integrity __ BOP Test __ Location clearance __ I / Mechanical Integrity Test __ Subsequent f°rm required 10' /--~oLfA.~ ORI6INAL SI6NED BY ~ Approved by order of the Commissi~l~94/SA4 LONNIE C. SMITH Commissioner Date -- Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company , , W~ll I-Ii~to~ - Initla! R~port - Da~ly~i Instructions: Prepare and submit the "Initial Rei~IT' on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spuddingr:~hould be summarized on the form giving inclusive dates only. . District ARCO ALASKA INC. ]County, I~r~[~or§~j~pE Field LISBURNE ]Lease o';~_~: 34631 Auth. or W.O.~0923 ITM DRILL IStat~K L3-1 [Well API: 50-029-21959 Operator ARCO ARC~)0W"I0000 Spudded or ~[~gun 07/14/89 Prior statue if a W.O, Date and depth as of 8:00 a.m. 07/14/89 ( TD: 223'( SUPV:GSW 07/15/89 ( TD: 1138'( SUPV:GSW 07/16/89 ( TD: 2258' ( 1 SUPV:GSW 07/17/89 ( TD: 2518'( SUPV:GSW 07/18/89 ( TD: 3187'( SUPV:GSW 07/19/89 ( TD: 4086'( SUPV:GSW 07/2O/89 ( ' TD: 5280' ( 1 SUPV:DBJ 07/21/89 ( TD: 5280'( SUPV:DBJ 07/22/89 ( TD: 5496'( SUPV:DBJ Date [Hour 0430 Complete rec~.~ac~ day reported ) DRLG MW: 8.8 VIS=300 23) MIRU RT. NU DIVERTER & FUNCTION TEST SAME. SPUDDED 17.5" HOLE @ 0430 HRS 7-14-89. DRLD F/ 115' - 223'. ) ,15) ) 2O) ) 60) ) 69) ) 99) DAILY:S100,717 CUM:$100,717 DRILLING DIRECTIONALLY DRILLED TO 1138. DAILY:S72,806 CUM:$173,523 DRILLING DIRECTIONALLY DRLD TO 2258. DAILY:S63,107 CUM:$236,630 PU MOTOR DIRECTIONALLY DRILLED TO 2518. ETD:S110,000 EFC:$-9,183 MW= 9.1 VIS:300 ETD:S200,000 EFC:$-26,377 MW: 9.2 VIS:300 ETD:S300,000 EFC:$-63,270 MW: 9.3 VIS:300 DAILY:S63,133 CUM:$299,763 TIH DIRECTIONALLY DRILLED TO 3187. DAILY:S54,046 CUM:$353,809 DRILLING AT 4086 ETD:S300,000 EFC:$-,137 MW: 9.6 VIS=300 ETD:S353,809 EFC:$100 MW: 9.7 VIS:255 DRILLED TO 3804. C AND C MUD. TOH FOR MWD FAILURE. TIH. TOH TO ORIENT MWD TOOL TIH. DRILLED TO 4086'. DAILY:S72,992 CUM:$426,801 ETD:S426,801 EFC:$100 ) TOH MW:10.0 VIS:250 94) DRLD TO 5280' (13-3/8" CSG POINT). TOH TO RUN 13-3/8" CSG. .6) DAILY:S53,145 CUM:$479,946 ETD:S450,000 EFC:$30,046 NO WH 13.625"@ 5264' MW:10.1 VIS: 90 TOH. RAN 13-3/8" CASING TO 5264 & CEMENTED SAME W/ 3500 SX AS III @ 12.2 & 500 SX G ~ 15.8. DID NOT CIRC CMT. PU DIVERTER. PERFORMED TOP JOB W/ 175 SX AS I @ 15.7. SET SLIPS. CUT OFF CSG. ND DIVERTER & BELL NIPPLE. DAILY:S451,065 CUM:$931,011 ETD:S900,000 EFC:$31,111 DRLG 13.625"@ 5264' MW: 9.1 VIS: 35 NO WH & BOPE. TSTD BOPE OK. TIH. DOC AND 10' OF NEW FORM. PERFORMED FIT TO 13.8 PPG EMW. DRLD TO 5496'. DAILY:S84,670 CUM:$1,015,681 ETD.:$1,020,000 EFC:$-4,219 The above is correct F°r f°rm preparati~n-~ distrib~'i°n' see Procedures Manual, Section Drilling, Pages 86 and 87. I~''t'' Drilling Supt. AR3B-459-1-D "! 1989 .~ ~.~.~.~ .,~ . ~ .~.: [Number all daily well history forms consecutively iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover ol:)erations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lltterim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I State ARCO ALASKA INC. I NORTH SLOPE I AK Field JLease or Unit LISBURNE I L3-1 Complete record for each day while drilling or workover in progress DOYON 9 Date and depth as of 8:00 a.m. 07/23/89 TD: 6745' SUPV:DBJ 07/24/89 TD: 8164' SUPV:DBJ 07/25/89 TD: 8865' SUPV:DBJ 07/26/89 TD: 9954' SUPV:DBJ 07/27/89 TD:10393' SUPV:DBJ 07/28/89 TD:10960' SUPV:GSW 07/29/89 TD:12017' SUPV:GSW 07/30/89 TD:12244' SUPV:GSW 07/31/89 TD:12977' SUPV:GSW IWell no. lO) 1249) 11) 1419) 12) 701) 13) 1089) 14) 439) 15) 567) 16) 1057) 17) 227) 18) 733) TIH 13.625"@ 5264' MW: 9.4 VIS: 44 DRLD TO 6745. TOH FOR BIT ~ 11. DAILY:S65,500 CUM:$1,081,181 ETD:S1,100,000 EFC:$-18,719 DRLG 13.625"@ 5264' MW: 9.5 VIS: 56 TIH. DRILLED TO 8164'. DAILY:S56,250 CUM:$1,137,431 ETD:S1,200,000 EFC:$-62,469 DRLG 13.625"@ 5264' MW: 9.4 VIS: 56 DRLD TO 8218. TOH FOR BIT # 12. TSTD BOPE. TIH. DRLD TO 8865. DAILY:S84,550 CUM:$1,221,981 ETD:S1,250,000 EFC:$-27,919 TOH 13.625"@ 5264' MW: 9.6 VIS: 44 Drld to 9954'. Dropped svy. TOH for bit # 13. DAILY:S73,289 CUM:$1,295,270 ETD:S1,295,270 EFC:$100 DRILLING 13.625"@ 5264' MW: 9.6 VIS: 51 TOH FOR BIT % 13. TIH. DRILLED TO 10393'. DAILY:S65,087 CUM:$1,360,357 ETD:S1,360,357 EFC:$100 TESTING BOPE 13.625"@ 5264' MW: 9.6 VIS: 55 DRILLED TO 10960. TOH FOR BIT # 14. DAILY:S59,824 CUM:$1,420,181 ETD:S1,420,181 EFC:$100 REPAIRING PUMP 13.625"@ 5264' MW: 9.9 VIS: 51 TESTED BOPE. TIH AND DRILLED TO 12017 W/ BIT ~ 14. DAILY:S80,656 CUM:$1,500,837 ETD:S1,500,837 EFC:$100 DRILLING 13.625"@ 5264' MW: 9.8 VIS: 47 DRILLED TO 12128. TOH F/ MWD TOOL. TIH W/ BIT # 14RR. DRILLED TO 12244. DAILY:S54,341 CUM:$1,555,178 ETD:S1,555,178 EFC:$100 CIRC 13.625"@ 5264' MW: 9.9 VIS: 60 DRILLED TO 12977. TOP OF SADLEROCHIT @ 8294' TVD (EST). CIRC LOW VIS SWEEP. DAILY:S57,336 CUM:$1,612,514 ETD:S1,612,514 EFC:$100 The above is correct Sig'nat~re~ ~, %k For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Drilling Supt. t 1989 ~ . N~ber ~'[~e*~r~ry forms as they a~%e~ach well. consecutively IPage no ARCO 011 and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all Cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District !lC°unty or Parish JState ARCO ALASKA INC. J NORTH SLOPE AK Field ~Lease or Unit LISBURNE I L3-1 Complete record for each day while drilling or workover in progress DOYON 9 Date and deptll as of 8:00 a.m. 08/01/89 TD:13078' SUPV:GSW 08/02/89 TD:13190' SUPV:GSW 08/03/89 TD:13563' SUPV:DBJ 08/04/89 TD:13611' SUPV:DBJ 08/05/89 TD:13611' SUPV:DBJ 08/06/89 TD=13611' SUPV:DBJ 08/07/89 TD:13611' SUPV:DBJ 08/08/89 TD:13611' SUPV:DBJ 08/09/89 TD:13611' SUPV:DBJ 19) 101) 2O) 112) 21) ( 373) (22) ( 48) 23) o) 24) o) 25) o) 26) o) 27) o) INSTALL NEW ROTARY CHAIN 13.625"~ 5264' MW:10.0 VIS: 57 TOH FOR BIT % 15. TIH. DRILLED TO 13078'. ROTARY CHAIN BROKE. REPLACING CHAIN. DAILY:S64,538 CUM:$1,677,052 ETD:S1,677,052 EFC:$100 DRILLING 13.625"@ 5264' MW:10.0 VIS: 60 REPLACED ROTARY CHAIN. DRILLED TO 13093. TOH F/ BHA. DRILLED TO 13190. DAILY:S64,276 CUM:$1,741,328 ETD:S1,741,328 EFC:$100 DRILLING DRILLED TO 13563. 13.625"@ 5264' MW: 9.9 VIS: 63 DAILY:S56,579 CUM:$1,797,907 ETD:S1,797,907 EFC:$100 JARRING ON STUCK PIPE 13.625"@ 5264' MW: 9.9 VIS: 63 TD'D 12.25" HOLE @ 13611' @ 1015 HRS 8-03-89. SHORT TRIPPED OK. CIRC. TOH TO 6167 AND STUCK PIPE. SPOTTED 60 BBLS BLACK MAGIC ACROSS DC. WORKED STUCK PIPE. DAILY:S55,017 CUM:$1,852,924 ETD:S1,852,924 EFC:$100 SCREWING INTO FISH 13.625"@ 5264' MW: 9.9 VIS: 55 WORKED STUCK PIPE. RETRIEVED PROBE FROM MWD W/ WL. RAN FREEPOINT. BACKED OFF IN HWDP I JT ABOVE JARS. TOH. REC 35 JTS HWDP. TIH W/ SCREW IN SUB, BUMPER SUB, OIL JARS, XO, 9-8"DC'S, XO, 34 JTS HWDP ON DP. DAILY:S75,343 CUM:$1,928,267 ETD:S1,928,267 EFC:$100 REAMING THRU K-SHALES 13.625"@ 5264' MW: 9.9 VIS: 50 SCREWED INTO FISH. JARRED FREE. TOH RECOVERED ALL OF FISH. TIH W/ BIT. REAMED FROM 5700-6203 AND FROM 11291-11762. DAILY:S73,235 CUM:$2,001,502 ETD:S2,001,502 EFC:$100 SHORT TRIPPING 13.625"@ 5264' MW:10.0 VIS: 49 TIH. REAMED FROM 11792-13611. CIRC. DAILY:S52,000 CUM:$2,053,502 ETD:S2,053,502 EFC:$100 RUNNING 9-5/8" CASING 9-5/8"@13590' MW: 9.9 VIS: 59 CIRC. SHORT TRIPPED FROM 13611-11291. CIRC. TOH. STARTED RUNNING 9-5/8" CASING DAILY:$69,820 CUM:$2,123,322 ETD:S2,123,322 EFC:$100 TIH W/ BIT 9-5/8"@13590' MW: 9.9 VIS: 53 RAN 9-5/8" CASING TO 13590'. CMTD SAME W/ 500 SX SS II. TSTD BOPE. TIH W/ 8.5" BIT. DAILY:S526,406 CUM:$2,649,728 ETD:S2,649,728 EFC:$100 JWell no. The above is correct s%e' x For forrr~r~pa~ation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ail cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District iCountyorParish IState ARCO ALASKA INC. I NORTH SLOPE AK Field Jhease or Unit · LISBURNE I L3-1 Date and depth as of 8:00 a.m, Complete record for each day while drilling or workover in progress 08/10/89 TD:13667' SUPV:DBJ 08/11/89 TD:14148' SUPV:GSW 08/12/89 TD:14375' SUPV:GSW 08/13/89 TD:14375' SUPV:GSW 08/14/89 TD:14375' SUPV:GSW 08/15/89 TD:14375' SUPV:GSW 08/16/89 TD:14375' SUPV:GSW 08/17/89 TD:14375 PB: SUPV:GLC 08/18/89 TD:14375 PB:14326 SUPV:GLC DOYON 9 (28) ( 56) (29) (481) (30) (227) (31) ( o) 32) o) 33) o) 34) o) 35) 36) DRILLING 9-5/8"@13590' MW: 9.1 VIS: 34 TIH. TESTED CASING TO 3000 PSI OK. DOC & 4' OF NEW HOLE. PERFORMED FIT TO 12.5 PPG EMW. DRILLED TO 13667'. DAILY:S77,247 CUM:$2,726,975 ETD:S2,726,975 EFC:$100 TOH 9-5/8"@13590' MW: 9.2 VIS: 36 DRILLED TO 14148'. CIRC TO TOH. DAILY:S61,619 CUM:$2,788,594 ETD:S2,788,594 EFC:$100 CIRC 9-5/8"@13590' MW: 9.2 VIS: 46 TOH W/ BIT # 18. TIH W/ BIT 9 19 AND DRILLED TO TD 14375. CIRC. DAILY:S70,030 CUM:$2,858,624 ETD:S2,858,624 EFC:$100 LOGGING 9-5/8"@13590' MW: 9.2 VIS: 48 TOH. RAN GR-DLL-SPECTROLOG-REL AND ZDL-CNL-GR-CAL. DAILY:S48,988 CUM:$2,907,612 ETD:S2,907,612 EFC:$100 CIRC 9-5/8"@13590' MW: 9.2 VIS: 48 RAN GR-FMT AND SLIMHOLE ZDL-CNL-GR-CAL. TIH. CIRC.SHORT TRIPPED OK. CIRC. DAILY:S161,193 CUM:$3,068,805 ETD:S3,068,805 EFC:$100 CMTG LINER 9-5/8"@13590' MW: 9.2 VIS: 48 TOH. RAN 7" LINER TO 14375'. CIRC & PREP TO CMT. DAILY:S65,360 CUM:$3,134,165 ETD:S3,134,165 EFC:$100 TSTG BOPE 7"@14368' MW: 9.2 VIS: 48 CMTD LINER @ 14368' W/ 184 SX ARC (CLASS G) CMT @ 14.8 PPG. TOH. CHANGED BOP RAMS. DAILY:S109,901 CUM:$3,244,066 ETD:S3,244,066 EFC:$100 DOC @ 14155 7"@14368' MW: 9.2 NACL TSTD BOPE. TIH TO TOL. NO CEMENT ON TOP. TOH. TIH W/ 6" BIT. NO CMT IN LINER TOP. TIH TO 14155 AND TAGGED CEMENT. DAILY:S47,621 CUM:$3,291,687 ETD:S3,291,687 EFC:$100 TOH LD DP 7"@14368' MW: 9.2 NACL DOC TO LC @ 14209. TSTD LINER LAP AND CSG TO 3000 PSI FOR 30 MIN OK. DOC TO 14326. DISPLACED WITH 9.2 PPG FILTERED BRINE. TSTD CSG TO 3000 PSI OK. TOH LD DP. DAILY:S95,762 CUM:$3,387,449 ETD:S3,387,449 EFC:$100 IWell no. The above is correct For form pr~paration and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well hislory forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit-the "Final Rel~o~t% on'the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitte~ a~;~ Operations ere suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report comptetl~ aa~t:~representat|ve test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ~ District County or Parish '/StateAKI ARCO ALASKA INC. NORTH SLOPE Field ILease or Unit LISBURNE I ADL: 34631 Auth. or W.O. no. I Title DRILL AL0923 API: 50-029-21959 Operator IA.R.Co. W.I. rrotal number of wells (active or inactive) on thisI Icost center prior to plugging and ARCO I 40. 0000 Jabandonment of this well I IH I Prlor status if a W.O. Spudded or W.O. begun ~Oate our 0430 SPUD I 07/14/89 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 9 08/19/89 ( TD:14375 PB:14326 SUPV:GLC cost center code L3-1 IWell no. RIG RELEASED 7"@14368' MW= 9.2 NACL TOH LD DP TO 600'. DISPLACED W/ DIESEL TO 600'. ND BOPE. NO DRY HOLE TREE. TESTED TO 5000 PSI OK. FR~EZE PROTECTED ANN. RELEASED RIG @ 0315 HRS 8-19-89. DAILY:S50,818 CUM=$3,438,267 ETD=S3,438,267 EFC:$100 Old TD Released rig Classifications (oil, gas, etc.) INew TD { PB Depth Date IKind of rig I Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. - Date Reservoir Producing Inter/al Oil or gasTest time Production O ' on test Gas per day P~mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abo~.ve~i ....... t X, X ~~'~ I pt ~3>~ - ~ Drilling Su . For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. a Number all daily well history forms consecutively I Page no. as they are prepared for each well. I AR3B-459-3-C OlvlNon of AtlantlcRIchfleldCompaay ARCO ALASKA INC. LISBURNE ENGINEERING DATE' 12-11-89 FROM: TINA KINCAID ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: '"~L3-01 '~'E'3-28 .~k4-2 ~<"r_4-10 ~_~L4-10 ~4-10 ¢-4-1o ..,~-31 COLLAR LOG COLLAR LOG PRODUCTION PACKER PHYSICAL FORMATION COMPENSATED NEUTRON LOG (POROSITY) DUAL INDUCTION (TVD) NATURAL GAMMA RAY (SPECTROMETRY LOG) DUAL INDUCTION COLLAR LOG RUN 1 RUN 1 RUN 1 RUN 1 RUN 1 RUN 1 RUN 1 RUN 1 RUN 1 11-29-89 ATLAS 11-30-89 ATLAS 10-31-89 11-24-89 SCH 11-24-89 SCH 11-24-89 SCH 11-24-89 SCH 11 - 18-89 ATLAS TAPES: L4-10 OPEN HOLE LOGS RUN 1 11-24-89 SCH L4-14 GCT DIRECTIONAL SURVEY RUN 2 10-14-89 SCH L4-31 GCT DIRECTIONAL SURVEY RUN 2 ....... TINA KINCAID ARCO ALASKA, INC. --..-- 700 G STREET; ATe 409 ~ ~3HORAGE, ALASKA RECEIVED BY: / ./--,, ~..~_ ..~--"~ TRANSMITTAL # 626 11-1-89 SCH 99510 RECEIVED Anchorage ARCO ALASKA INC. LISBURNE ENGINEERING DATE' 11-8-89 FROM' TINA KINCAID ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: L3-1 ~"L3-1 "~" L3-28 [_4-2 ~L4-2 ~L4-2 '~.~.' L4-2 L4-2 ~. L4-2 ~ L4-2 ~ L4-2 ~ L4-31 '~' L4-31 '~' L4-31 LOGS: LGI-06 LEAK DETECTION L2-6 COLLAR LOG k~' INJECTION PROFILE · L3-1 COLLAR LOG CEMENT BOND LOG CEMENT EVALUATION COLLAR LOG PHYSICAL FORMATION COMPENSATED NEUTRON LITHO DENSITY- POROSITY COMPENSATED NEUTRON LITHO DENSITY- RAW DATA REPEAT FORMATION TESTER NATURAL GAMMA RAY SPECTRA LOG DUAL LATERLOG GAMMA RAY COLLAR LOG ACOUSTIC CEMENT BOND LOG CEMENT BOND LOG CEMENT EVALUATION LOG GCT GYRO DIRECTIONAL SURVEY RUN 1 10-12-89 CAMCO RUN 1 10-25-89 ATLAS RUN 1 10-13-89 CAMCO RUN 1 10-20-89 ATLAS RUN I 10-23-89 SCHLUMBERGER RUN 1 10-23-89 SCHLUMBERGER RUN 1 10-27-89 ATLAS RUN 1 10-13-89 ANADRILL RUN 1 10-22-89 SCHLUMBERGER RUN 1 10-22-89 SCHLUMBERGER RUN I 10-22-89 SCHLUMBERGER RUN 1 10-22-89 SCHLUMBERGER RUN 1 10-22-89 SCHLUMBERGER RUN 1 11-1-89 ATLAS RUN 1 11-1-89 ATLAS RUN 1 11-1-89 SCHLUMBERGER RUN 1 11-1-89 SCHLUMBERGER RUN 1 11-1-89 SCHLUMBERGER TAPES: L4-2 OPEN HOLE LOGS L4-2 RFT RUN 1 10-23-89 RUN 1 10-23-89 SCHLUMBERGER SCHLUMBERGER · SIGN AND RETURN TO: RECEIVED BY: ? STATE OFAL~A~ TRANSMITTAL # 625 TINA KINCAID ARCO ALASKA, INC. 700 G STREET; ATO 409 '- DATE: 10-6-89 FROM: TINA KINCAID ARCO ALASKA INC. LISBURNE ENGINEERING ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: ~ L4-31 NATURAL GAMMA RAY SPECTRA LOG RUN 1 9-6-89 ~ L4-31 COMPENSATED NEUTRON LOG RUN 1 9-6-89 ~ L4-31 COMPENSATED NEUTRON LITHO RUN 1 9-6-89 ~ L4-31 -"-- 'L4-31 ~ L4-31 ~ L4-31 DENSITY - POROSITY COMPENSATED NEUTRON LITHO DENSITY- RAW DATA DUAL LATERLOG REPEAT FORMATION TESTER PHYSICAL FORMATION RUN 1 9-6-89 RUN 1 9-6-89 RUN 1 9-6-89 RUN 1 9-6-89 SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER TAPES: .1GCT DIRECTIONAL SURVEY OPEN HOLE LOGS RFT DATA L4-31 OPEN HOLE LOGS RUN 1 8-26-89 RUN1 9-14-89 RUN1 9-15-89 RUN 1 9-7-89 SCHLUMBERGER ATLAS SCHLUMBERGER SCHLUMBERGER SIGN AND RETURN TO: TINA KINCAID ARCO ALASKA, INC. 700 G STREET; ATO 409 ANCHORAGE, ALASKA 99510 RECEIVED BY: EXXON BP STATE OF ALASKA TRANSMITTAL # 623 Alaska 0il & Gas Cons. Commissiot Anchorage July 12, 1989 Telecopy No. (907) 276-7542 Richard B Gremley Regional Drilling Engimeer ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit/Ltsburne L3-i ARCO Alaska, Inc Permit # 89-75 Surf Loc 287'FNL, 549'~, Sec 22, TllN, R15E, UM Btmhole Loc 895'FNL, 2125'FEL, Sec 9, TllN, R15E, UM Dear Mr Gremley: 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. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witnes~ testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly ffou~rs ,~ ~ C~X7 Chat~-e~ffton ?/ Chairman Alaska Oil and Gas Conservation Commission BY O~ER OF THE COM~vIISSION jo Enclosure C~ Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA L _ AND GAS CONSERVATION CC...~vllSSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill I~ Redri,l []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenF11 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Pad 21' RKB 60 feet Prudhoe Bay Oil Pool 3. Address 6. Property Designation Lisburne Oil Pool SHL: ADL 28322/ALK 232( P.O. Box 100360, Anchorage, AK 99510-0360 ............. 4. Location of well at surface 7.~'0~[t 6'r"¢ro~¢ '1~ .... 11. Type Bond (see 20 AAC 25.025) Prudhoe Bay/Lisburne Statewide 287'FNL, 549'FWL, Sec.22, TllN, R15E, UM At top of productive interval 8. Well nu .mber Number 1470'FNL, 1970'FEL, Sec. 9, T11N, R15E, UM L3-1 No. U-630610 At total depth 9. Approximate spud date Amount 895'FNL, 2125'FEL, Sec. 9, T11N, R15E, UFI 07/13/8~ $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line From L3-30 14242'FID 31 55' ~ TD feet 120' @ 100' feet 2560 91 67'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500' feet Maximum hole angle 54 0 Maximum surface 3372 psig At total depth (TVD) 4490 psig 18. Casing program Settin~l Depth size 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' 35' 35' 115 115' 2000# Polymer 17-1/2' 1:3-3/8' 68.0# L-80 BTC 5421 34' 34' 5455 4000' 3500 sx AS I i I & 500 sx Cl. G 12-1/4' 9-5/8'! 47.0# L-80 BTC 13423 33' 33' 13456 8705' 500 sx Class G w/Addi 8-1/2" 7" 29.0# L-80 BTC 996' 13256' 8587' 14242 9167' 200 sx Class G w/ 19. To be completed for Redrill, Re-entry, and Deepen Operations. self stress additive 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 I nte rmed i ate Production JUl ~'~ ~'~ ~'~ Liner Perforation depth: measured Aiaska 0i! & 6as Cons. ',*','~ '"~'" true vertical 20. Attachments Filing_ fee ~ Property plat [] BOP Sketch E~ Diverter Sketch ~ Drilling program E~' Drilling fluid program ~Timevs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe~~~ Title Regional Drilling Engineer Date~/~/~,. Commission Use Only (MDD) PD3/082 Permit Number APl number I Approval date I See cover letter ?? _ 50- - z / ? ?I 07/-I 2 / 89I for other requirements Conditions of approval Samples required [] Yes ~"No Mud Icg required [] Yes .,l~"No Hydrogen sulfide measures ~' Yes [] No Directional survey required ,]~"Yes [] No working pr ssure o'r - E 2M; [] 3M; J~ 5M; [] 10M; [] 15M Required Other: Y(/7~" ~~~/~ ~' Comm,ss,oner' . byorderof Approved b the commission Date .! Form 10-401 Rev. :12-1-~5 Submit irv :riplicate ives LISBURNE L3-1 PRELIMINARY WELL PLAN DRILLING PROCEDURE 1) MI RU Doyon 9. 2) Drill 17-1/2" hole to 500'MD/TVD. Kickoff and build angle at 2.5°/100'MD to 54o58' in a N 15°9' W direction. Maintain hole angle and direction to 13-3/8" casing point at 5455'MD/4000'TVD. 3) Run and cement 13-3/8" casing to surface· 4) Drill 12-1/4" hole to 13456'MD/8705'TVD. 5) Run and cement 9-5/8" casing. 6) Drill out 9-5./8" casing and 8-1/2" hole to TD, 14242'MD/9167'TVD. 7) Run open hole logs. 8) Run and cement 7" liner. 9) Clean out liner and change over to brine w/diesel cap. 10) Install dummy hanger and master valve· Release drilling rig. 11) Run cased hole logs. 12) MIRU completion rig. 13) Run 2-7/8" single completion string. 14) Release completion rig JUL 15) Perforate and stimulate. Alask~Oil&Gas-~- o NOTE' a) Excess non-hazardous fluids developed from well operations and as necessary to control the fluid level of the reserve pit, will be pumped down the annulus of an offset well. The annulus will be left with a non-freezing fluid during any extended interruption in the pumping process. The annulus will be sealed w/250 sx of cement followed by Arctic pack upon the completion of the pumping process. b) The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AA625.033. c) Maximum surface pressure is based upon BHP of 4490 psi at 9342'TVD, less an oil column to 8409'TVD, less a gas column to surface. d) Wells within 200' of L3-1 are' L3-05' 120' away at IO0'MD/iOO'TVD L3-02' 175' away at 800'MD/8OO'TVD e) No potential hazardous levels of H2S are anticipated in this well. 082/PD3 lOOO 0 1000 2000 3000 4000 5000 6000 7000 2000 300O 4000 5OO0 7000 8000 9O00 10000 .............. I I I I I I I f I I I I I f I I I I I I f I I I I f I I I I I I I I I f I I f I I I I I I I I I I f RKB EI.RVATION 60' ' ' 20" Casing TVD=I 15 TMD=-ll5 ~oP ~=,oo AR(~O ALA SKA, D ~C. ~.o L3-1 7.5 [ ,,o~.o, SCALE: 1"- Q.°s SHL: U 1 IN 15E 22 287' FN . 549' FWL bo THL: U 11N 15E 9 1470' FN' 1970' FEL }~ BHL: U 11N 15E 9 895' FN[2125' FEL 5 ~3o.o N159' ~'i'~o '~['-~ EOC TVD=2353 T~ tD=2658 DEP=-942 13-3/g"C nin~ TVD=4000 TMD::5455 DEP=-3204 ~ ~5~ ~305 D ~=3891 A~GE ~G[ E = 53 58'~ ~ K_,0 ~7435 T, ~=11295 D~=7927RECt~i,,~ 70 ~11695 D~= Alasl~o. Oil & Gas ~3ons. adleroc~i T~=8300 ~=127 57 DEP=9118 Kav~ ~=8{00 T~=13277 D~=)530 9-5/S" C~mg ~=s' 05 T~=13456 D~=9675 _ ~ _ Top W~oo (Target) ~=t 735 ~13506 D~::~15 - ~ne6 ~ D=8810 ~13634 )~=9818 ~ne 5 ~8935 T~=13&.7 D~=9990 Zc ~e4 ~=9025 ~=14000 D~=10114 OWC ~9110 T}~=141~ D~=10231 ~ ~=9167 T~14242 D~=1031( .............. i ....................... ~ .................. 7000 8000 9000 10000 11000 12000 13000 1400( VERTICAL SECTION ARCO ALASKA, INC. L3-1 N159'W E - W COORDINATES 116i ,Ru.u ...... :,~u.u.u ...... :au.u? ...... :zuy? ...... 7mUU ....... u ......... ,,~.,,¥ ....... ~OYYooo- 100( [} 10000 900 }000 800 8000 700 7000 60( 6000 50( 5000 40( ) 4000 30( ) 3000 20( ) 2000 10( ) 1000 0 0 .~o%oo ...... ~,~oo ...... ~oo...~ooo ...... ~,~oo ............ ~oo ....... ~.,~ooop~, rARCO ALASKA, INC. L3-1 E - W COORDINATES -200 -100 0 100 200 300 400 500 400 400 300 200 L3-05 I Z -100 -200 -300 -400 L3-15 -500 -200 3182 1731 3O97 1646 3008 58 2! t18 1980 77 2725 ~9 ~3 263'.' ~m 233s L3-12 3~ ~ 36~ ~ ~600 ~. 3~0 ~43 ~ [2 ~ l~5 ......... ~ .......... , ............................................ ~208 300 200 100 100 3930 o o 400 -200 -300 -400 -500 - 100 0 100 200 300 400 500 E - W COORDINATES L3-1 MUD PROGRAM Plas Density Vi sc. Depth (TVD) #/gal (CP) Yield Point Initial 1OM #/1 O0 ft2 Gel Gel FL CC/30M % % pH and Oil Solids Type of Mud Surf 8.8 Funnel to to 160- 13-3/8" 9.2 300 Csg Point 40-60 30+ 50+ 25 0 8 Gel-Benex Spud Mud Operate all solids removal equipment to maintain PV as low as possible. cement contamination. 13-3/8" SET 13-3/8" CASING--- Csg Shoe 8.8 Minimum 2 2 5 15 to to Possible to to to to K-lO 9.2 4 5 10 25 Pretreat with Bicarb or soda ash for 3.5 Low Sol ids to Non-dispersed 6.5 Operate all solids removal equipment to maintain weight as low as possible. K-lO 9.2 12 6 2 5 4 2 4 to to to to to to to to to 9-5/8"Csg. Pt. 10.4 20 10 4 8 6 5 8 Low Solids Non-dispersed Low Lime .25 to .50 ppb excess lime To control potential shale problems in K-lO to K-2 interval, increase mud weight only as required. DO NOT weight up prematurely. Use low viscous pill sweeps to clean hole as needed. Expect some possible gas cutting below the top of the K-lO shale. Use degasser as necessary. Mud weights should be kept as low as possible to minimize differential sticking problems in the Sadlerochit Sand. Should torque or drag become excessive, treat with medium nut hulls and screen out at shaker. If torque or drag continues, treat system with crude oil as required. Maintain fine screens on shakers to allow use of 75% of screen area. ................ SET 9-5/8" CASING --- 9-5/8" pH 10-12 water base Csg. Shoe 9.3 12 10 2 5 8 0 8 mud with 30,000 ppm Cl. to to to to to to to to to 7" Csg Pt 9.5 20 20 4 8 15 5 12 .............. SET 7" LINER ........................................... On daily service company mud report, log hours that desilter, desander, and degasser are run; and the number of cones in operation and size of shaker screens being used. Report volumes injected or dumped to reserve and water used. 2This mud plan is a guideline only. These exact mud properties, including mud weight, need not be maintained if rig supervisory personnel feel hole conditions warrant otherwise. Any radical changes should be discussed with Anchorage before implementation. 3Verify correct mud properties after circulating bottoms up prior to cementing 7-5/8" casing.~:.~f 4Verify correct mud properties prior to cementing liner after circulating bottoms up. 04/17/89 PD3/077 13-5/8" 5000 PSiI BOP STACr~ DIAGRAM ACCUMULATOR CAPACITY TEST ANNULAR PRFYENTER PIPF RAMS BLI ND RAHS DRILLING SPOOL PI P£ RAMS DRLG SPOOL CSG SPOOL 13-3/8' STARTING HEAD ALL BOP EQUIPMENT 5000 PSI RATED 11. 12. 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHAROINO PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST -1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING dOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. :5. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF :5 MINUTES, THEN TEST AT THE HIGH PRESSURE. 6.INCREASE PRESSURE TO :5000 PSI AND HOLD FOR A MINIMUM OF :5 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :5 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :5 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST :5 MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST :5 MINUTES. 1:5.BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. 1 4. TEST STANDPIPE VALVES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JO 8-26-85 SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE 20" 2000 PSI DIVERTER RISER IFLOWLINE 10" BALL VALVE 10" BALL VALVE I CONDUCTOR ~,i~::'.:i ~.~. NOTE' ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINES I I I I i r- I , ; , RIG MODULES ~ I I NOTE' 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 TYPICAL MUD PIT SCHEMATIC TRIP TANKS BBLS) DEGASSER (83 BBLS) DESILTER (97 BBLS) ISHAKER I PILL PIT (36 BBLS) DESANDER (97 BBLS) (36 BBLS) SUCTION PIT (448 BBLS) MIX PIT (122 BBLS) DRAWING IS NOT TO SCALE NOTE: SYSTEM IS EQUIPPED WITH A DRILLING FLUID PIT LEVEL INDICATOR WITH BOTH VISUAL AND AUDIO WARNING DEVICES AND A FLUID FLOW SENSOR LOCATED IN THE IMMEDIATE AREA OF THE DRILLER'S CONSOLE. JG 7/24/87 CHECK LEST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~t/9~_. 7/~/~'~ 1. (2) Lo.c (~t~fhr u (8) Admin./~ ~JZ~ 9. (9 thru ~3) ' 10. (10 and 13) 12. 13. (4) Casg ~.~.~. (14 thru 22) (23 thru 28) (6) (29 thr~ Geology: En~$nee~ing: rev: 01/30/89 6.011 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company Lease & Well No. YES NO Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Es operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force ................................... Is a conservation order needed ...................................... Is administrative approval needed ................................. '. Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ T For 29. 30. 31. 32. Is a diverter system required ....................................... ~ i Is the drilling fluid program schematic and list of equipment adequate~ ., Are necessary diagrams and descriptions of diverter and BOPE attached..~ Does BOPE have sufficient pressure rating - Test to ~>OO psig .. ~ ...... Does the Choke manifold comply w/API RP-53 (May 84) .................. .,, Is the presence of H2S gas probable ................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,4D,,' 3 5z '3/ ' L_ 3-/ exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. .... Are seismic analysis data presented on shallow gas zones ............ __ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Additional Remarks"': .) 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. COMPANY NAME : 4, RC0 ALASKA, NELL N~M:~ : L3-! :LZSBURNE ~I/L.g~ NA''r~ ~4:: : PRUDHOE. ~A'Y./:LiS~URN:E: ~:O~OUGH :: NORTH SLOP~E .STAT~ :: ~L~SK~ ~'Z NUM~E~ : 50-029-21959 qE~ER:ENCE NO : 73~9~ POOL MICROFILMED IiS TAPE VERiiFIC '~ ~ I ~ ~CHLUMBERGER AL.~SK.A COMP!JTING CENTER 3-0CT-1989 i4:27 PAG=' · ~ ~,~ REEL H~AD~R SERVICE NAME : GCT DATE : '~9/10/ 3 ~RIGIN : FLiC REEL NAME : CONTINU~TZ~N PREVIOUS REEL : COMMEN'T : GCT, ARCO~ L3-1, P:RUOH~ B ~.~ AY/LISBURN~ POOL, 50-029-21959 SERVICE NAME : GCT D~TE : S9/10/ 3 0 R I '~.~. I N .' ~= :L 'I C TriPE NAME : 7~4~4 CONTiNU4TIgN ~ : 1 PREVIOU.S T~PE : COMMENT : SC'T, ARCO, L3 I~ P~qU'~HOE ~&Y/L!S~URN5 POOL, 50-029-21959 -~--,- --,., FILE FILE NAME .: GCT ,,00t SERVICE ' ~LIC VERSION : O0tfi~Z M4X REC SIZE : FTL5 - ~ ~ ~ Y~:'E : LO LAST ~.ILE : COMPANY N:~ME: WELL: FIELD: BOROUGH: STATE: ~'"' M ""'" D, ': ,~RCO fiLASKA, INC. t3-1 LiS~URNE U~.~, ..... E ~AY/LIS:~:URNE PJOL NO~TH S L 3 P .:E AL ~SK~ 50-029-21959 LOCfiTION: 2'8'"t,' ';:::NL E, 550' SECT"ON'.,. ,, 2,'s',. TOWNSHIP. -. ~.IlN RANGE: !SE PERMANENT D4TU~: ;'~SL. ELEVaTiON:. ~. O ,IS TAPE VERIFICATION LISTING ;CHLUM'BERG~R ALASKA CONPUTiNG C~N'TiER 3-OC'T-1989 !4:Z7 LOG MEASURED FROM K~, 60 ABOVE DE~ANENT DATUM DA'TE LOGGED: RUN NUMBER: TO ~RiLLE~: TO LOGGER: 26-AUG-89 ONE t~325 14319 CASING t: CASING 2: 9 5/8" 4'7 LB @ DRILLER OiEPTH OF 0 TO 13590 ?" 29 h2. @ CRIL'LER D~PTH OF l~B05 TO 14368 AND cLOGGER DEPTH OF 13300 BIT SiZE 1: 12 BIT SIZE ,Z: 8 1/2" TYPE FLUID IN HOLE: BRINE DENSITY: 9.2 TIME LOGGER ON ~:OTTOM: Z~:~! 2.5-AUG LOGGING OIS'TRICT: 4615 ~OGGING ENGINEEr: W,~RNER WITNESS: RAEL/WALZ TOOL NUMBERS: GCAO GCPC 701 TCC4 GCM 7t~ GCEC 713 GCID 37 TCM 1 07 DATE JOB STARTED: 03-0CT-89 JOB REFERENCE NO: 7'3494 LDP/~NA: J. KOHRING COMPUTING C=NTER ~_ REMARKS CLIENT SUPPLIED AZIMUTH OF 3~4. B5 (N15 OW) USED IN COMPUTATION. THIS LIBRARY T~PE ~LS0 INCLUDES EXTP~DOLATEO V,&LUES O~ GCT O~T~ FROM ~CT LAST REAO!NG (14242,6')TO DRILLER'S DEPTH (14375'). TABLE TYPE : CONS T'UNI VALU DEFI CN FN WN NAT I ST AT COUN SECT TOWN RANG ARCO &L&SK~, INC. P~UDHOE BAY/LISBURN5 POOL L3-1 LISBURNE USA AL~SK~ NORTH SLOPE 22 11R COMPANY NAME FIELD NAME WELL NAM5 NATION ST~TE OR P~OVINC~ COUNTY SECTION TOWNSHIP .IS 'TAPE V~RZ~I.C~TION LISTING ~CHLU,,~mRG:ER ~LASK~ rOMPUT~NG CFNT~ T UN ~ FL ENG~ SON A P I N P~GE: V,~LU .2:~T' FNL & 55'0~ FWL 50-02.9-2~959 DEFI FIELO :LOCATION ENGINEER'S NAME SERVICE ORDER NUMB~ER AP1 SERI~L NUMSE~ 'TABLE TYPE : CURV O E'PT GDEP V D:E F D E V I H L A Z NSDR EWDR CWEL DEFI r~,-PTH C ' ' ~,~: HANNEL NA GYRO DEPTH TRUE V~ERTIC~L DEPTH AS CHANNEL O E V I ~'T I 0 N DEVIATION AZI~UTH NORTH SgUT~q DRIFT EAST WEST ODIFT CDNDDNENT CURV~T'URE ~ THE W~LL ~'"'~-,- DATA FORMA'T SPECi~:ICAT,ION, , RECORD ~, SET TYPE - 6a. EB ~, TYPE REPR CODE VALUE .IS TAPE VE~IFiC;~:TION LISTING ~CH'LUMBERGER ALASK~ CCMPOTZNG CENT!ER 3-0CT.-1989 14:27 SET TYDE - CHAN NAME SERV UNZT SERVIC'E ~Pi APi A.P! A.P! ~ILE: NUMB NUMB SZZE REPR ID OROER ~ :LOG TYP:: C'LAS.~ ~gg NU,~ ...... SAM~ ~L ~ COg~ DEFT FT 335552 O0 GOE~ GCT FT 335552 9'9 VO~P GC'T FT 3355~2 99 DEVI GCT D~G 335552 99 : G ~ .35 ~ ~ 2 99 NSCR GCT FT 335~52 99 EWD~ GC'T F'T 335:552 99 CWEL GCT C/HF 335552 99 OOO O0 0 I 1 I 4 68 000 OO 0 I I i 4, 68 009 OO 0 1 I 1 4 68 620 II 0 I I 1 4 68 520 11 0 1 t 1 4 68 $20 11 O 1 I 1 4 68 620 11 O 1 1 1 ~ 68 OOO O0 0 1 1 I ¢ 68 ~ROCESS (HEX) 0000000000 O00000OO00 O000OO0000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA DEPT. 655.35.500 GCEP.GCT 30.000 VDEP.GCT HLAZ=GCT 0,000 NSOR,GCT 0,000 ~WOR,GCT DEP'T. 65300.000 GDEP.GCT 785,!00 VDEP,GCT HLAZ.GCT 352.297 NSDR.GCT !9.817 EWDR.GCT D~EPT, 65400.000 GDEP.GCT 8399.996 VDEP.GCT HLAZ,GCT 3~2,652 NSOR.GCT 5173,112 EWDR,GCT OEPT, 6S318.000 GOEP,GCT 14375,000 VDEP,GCT NLAZ,GCT 343,201 NSDR,GCT 9775.~10 EWDR,GCT 30.000 DEVI.GCT 0.000 CWEL.GCT 783.937 DEVI.GCT -'7. ? 96 C W E L. G C T 5728,053 DEV!.GCT -1906.302 CWEL. GCT 9171,500 DEVI.GCT -3499.152 CWEL..GCT 0,000 0,000 8,624 2 · 890 5?, 925 0,462 46,433 0,000 ** ENO 0¢ DATA ** ¢~-** FILE TR.AILr- R FILE NAME : GCT oOO! SERVICE : FLIC VERSION : O01lOZ DATE : 89/!~/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FIL~ : *-**~- TAP: SERVICE NAME : ~CT DATE : 89/10/ 3 ORIGIN : :LIC TAPE NAM~ : C~N'TINUATION '~ : 1 PREVIOUS CBMMENT : GCT~ ARCO~ LB-i~ PqU9N:.3E ~Y/LISBURNE P~OL:, 50-029-21959 .tS TAPE VERIFICATICN LISTING 3CHLUMSERGER ALASK~ COMPUTING CENTER 3-0CT-1989 14:2'7 PAGE: SERVICE NA~E : GC'T DATE : 89/.10/ B ORIGIN : ~LIC REEL N;~E- : 73~.¢ CONTZNU.~TZDN f : PREVZgUS RE~L, : COMMENT : GCT, ~.RC~3~ L3-1~ PRUDHDE ~.~.Y/L]S~URNE PO~L, 50-02g-2~g59 PqOGR~,M: L T SC, Z~N ._ ON. 5.1 PART NUMEER: W57~O-PE32 Start of execution: Sat **~* ~EEL HEADER LZS 89108112 ATL~.S 01 'LIS CUCT""HER,... ,,., FOP. MAT, T~,PE'.. *'*** TAPE HEADER LIS S9/08/12 3929 01 'OPEN HOLE-WITH. unLL, ZDL'CN,SL MICRO.FILMED F.TL= ¢ 1 **** FILE H;ADER **** HAIN .001 1'324 CN : ~RCO ,~L~SKA WN : L 3 ' 1 ~N : LZSSURNE COUN : NORTH SLOPE STAT : AL&SK& ZNCORPOR.~TED FORMAT RECORD (TYmE~ 64) ONE DEPTH P~R FR&ME TAPE DEPTH UNiT : F-T CURVES NAM$.., COD= t SF' 68, I ~ S~MPLE~ 1 1 1 UNIT 5YTES MV 4 AP1 4 OHMM 4 ~MM ~ 5 RMLL 6¢ I OHMM 7 3EV 68 1 DEG :~ RB 68 1 C:EG o r-g 6~ 1 VOLT In ~3 6~ 1 ~T/M 1 t ~S .5~3 1 VOLT 12 ZO 65 1 ~MP 15 TTEN 6,~ 1 LB 16 KTH 68 1 PCT 17 TH ~,:~ 1 oCT 1~ K ¢8 1 ~CT 19 U 63 1 CTS gAT,& T ~I'-'lP SPD TTEN RMLL =S KTM O) 966 5YTES * DEV TH IS K RS ED CHT U 14388,000 O.O0000CO O.OOOO000 34~ -80.00000 0.?000000 O.OOO000O 0,0000000 0,0000000 0.0000000 O.OOO0000 0.0000000 0.2000000 0.0030000 O.O000000 O.O000000 0,2000000 0.0000000 0.0000000 -10.00000 14338.000 154.9778 9.999031 5205.961 -80.00300 103.4619 375.9807 13. B42~.~; 4 27,3~$94 360,2971 12.9~353 0.3~99736 2,664165 43.35735 21 ~9402 335.1641 1t64,045 !,335120 1~288.003 156.7'555 9.999001 4070 4'~~ -!7.84024 75,1878~ 397.4326 23.55382 31.83270 365.7642 256.0276 2,774586 24.79610 2,583561 639.4741 0,3393367 23,46176 44~,6192 895.6113 0,910097~ 14~38.00~. 137.5710 9.99o001 4996.625 -35,107C6 317,3250 364.5024 14. 24303 23.35,593 366. 8306 18.58917 O,OOOOO00 446,3330 1 ,456661 63.9045t 0.3017847 338.7288 572.8767 897.662¢ t.0e1529 141~.0~'~ 1571499~ ¢ 999~01 4Q70,051 -30.87721 46.20471 389.0039 1.63672~ 13.73293 352, ~063 89.99591 68.07611 3.67~058 255. '0640 O, 73091646E-01 58.12148 426.5469 874.7021 0.9800200 14138.000 156.3014 9.990001 5023.434 -23.43513 372,4829 ~30.0037 O.O00000O 15,34693 366 70'~ t¢.70834 O,O00OO00 319,4026 1.363010 78.2:5079 0,6648868E-01 210.5157 435.8508 919,5139 1.365937 t 40 88 · 000 156.059g 6.633485 73,02271 /,~ /,~ 1 3.53,9702 51.1 74 08 2.035337 41.91148 459.3447 14038.000 9.999001 5326.078 1 39..~,8. OOO 1 ":4 ~1 69 5123,570 93:¢. 1S 4. z.,. P4r-_ 9.909001 4.',~33.754 1 33:~;~ · 000 154.1'402 I0..~53g0 4967.6o4 155,7927 9.9~9~01. ~ 13788.000 153.0521 1 O. ~847.871 13738.080 152.4539 10.65390 4S65.~1~ 136~$.000 1S2.0054 10.10820 5~46.5~4 13638.000 151.4205 9.~o9001 5204. .992 1358,8.00'3 1~0.51~? t$.88970 4791.o34 1353~.303 -1.78~643 165.3372 5~9.8210 2.155183 17.27022 ¢t .5!225 1~.3.1278 10.20833 9!.~3503 467.0~54 2Z.40892 -26:. 57561 265.575-? 404.0320 -43.31140 25S.5413 23.00250 -40.88171 .45.37703 28Z.44~0 45.24345 -50.2t143 52.Z2330 2441 11.2P_583 -~.3. 08772 2~.42517 64.37477 9.054678 -22.65092 38.75211 49.82030 8&.07187 -27,899Z5 10.42703 -0.6938595E-01 49.99051 0.2000000 16,29663 365.905~ 19,60046 0.0000000 97.554~8 356.~272 407.2344 3.~69495 37.90086 366.9t00 140.~S42 0.5545763 21.27048 363.5586 48.3t126 35.96754 354.~:863 61.9793'7 0.5430675 365.195o 299.8757 1.433908 23.0!895 363.6531 ~5.7!342 25.45679 364.6067 106.0591 0.0000000 90 1~770 363.3086 171.7989 8.113668 5! ,59840 168.003~ 6.3014~2 0.0000000 0.0000000 443.1040 1.530560 79.97971 O. ~2713t3E-01 7.462109 1.727016 1095.467 ~.28755© 49.94864 580. 4099 0.4963~61 157.854:$ 0.959907~ 138.3689 0.1620973 7:2.25159 1 .445773 156.0616 0,4864067 16 =7321 664.61~0 0.7497946 60,26659 2,579504 298,7881 0,2466162 10.73393 4.954618 310.0422 0.1292824 5.750569 3.795923 499.8955 1.774191 0.1000000 14.12788 140.4345 0.~603056 0.2000003 g 00' "' "· ,3 ,,~ 00 :n 5e9.7148 9o7.8245 1.183243 ~; ~4,31 62 211 1032.269 2.6~1933 46.95255 488.3~77 873.2021 2.106413 136,6476 ~9 C033 913.7605 ! .214066 63.3~023 31!.7507 2.056993 16.24617 346.4102 873.6282 5.421760 36.1!873 317.7412 394.5315 I .514277 7.936866 79,$6069 1219.~60 1,368795 3.809468 69.23688 1t94.572 0.8855914 0,1000000 0.4616109 932,9653 0.2978718 0 ~O0~O00 0.00,-~ n_nnnnnnn TOTAL O&T~ RECORDS START*NG, . ~ TAP~ DEoTH. ~ , FILE 14,7 ENDING T~PE DEPTH 13508.00 FILE 2 ***'* HT. LE HEADER **** REPT .002 1024 F'~RMAT ~'ECORD ('"' ,~ ONE DEPTH ~R TAPE DEPTH UNiT 19 CURVES : NAM E 1 SP TEM? 5 RS RMLL 7 D,~V 9 E r3 10 SPO 11 ~S 12 ID 1~. IS lZ, CHT I ~ TTEN 15 KTH !7 TH 18 K t9 U ODE S&~PLS~ UNIT 68 I MV 6~ I APi 6& 1 OHMM 68 I OMMM 68 I OHMM 68 t 3EG 68 1 68 1 VOLT 6~ t FT/M 68 1 VOLT 6~ 1 AMP 68 ! AMP 68 1 L~ 53 1 ~ ~' 1 ~'CT 6~. 1 P~T 63 I mCT 68 1 PCT BY 4 4 4 4 4 TES O&T& RSCORD DEPT,q S~D TTEN (TYPE# ~P RMLL KTH 966 ~YTES * T EMP ID TH IS ED CHT U 143S$.000 -9~9 P~OO -999.2500 -~'99.250~ -9~9 25n0 -'~99.2500 -999.2500 -~g.2500 -999.2500 -999.Z500 -~c9,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2S00 -999.2500 14288.00C 9.999001 14238.000 291,7473 9.9o9001 4g03,480 1418~8.000 82.01790 9,909001 4996.441 1413~.000 219.2285 9.999001 14038.00!3 3~,05810 9,9~o001 498~,043 1~03~.000 260.3235 9.999001 4~71.~53 139~8.000 5.247470 9.999001 515!.428 13938.000 4~ 42~91 9.999~! 4909 .770 13888.000 148.7o78 9.990001 481~.430 13838,000 35.30~06 9.9~900t 36. :$9911 3~3.9312 16.544~3 -49.2796..0 3! .64063 398,0134 21,89127 -57.0]022 57,79510 577.4565 13.55955 -54.30406 38.64854 404.8552 . __~ u -34.45045 1!32 ~' ..c,~4 439.1638 5.000504 -32.80996 4~,52745 437.055~ 13.21264 -47.18210 125,521.6 601 .1475 2.9a9789 -47,60603 57,65396 154.7810 .83.13712 -60.89059 53.57413 474.8765 23.11119 -53.26784 118.1569 505.72t4 ~.003126 -63.21384 !01.7339 240.61~9 4.70176~ 36:3.6106 12.68788 1,159448 364,0403 228,057~ 0,~1~37~ 15~,1609 365,811¢ ,60274 0.452~127 156,5831 ¢~.0679 6;0.79234 0.~264063 t55.3031 365,5513 19.93356 0,0000000 !54,~296 764 45~1 139,3778 0,524~933 1.~3 .5824_ 366.7891 0,0000000 ~2.9301 358,6092 417,4001 7.066343 152.7612 365.8989 137.367~ 1.098456 152 5240 364.5479 44,74368 O. ,.¢u.O 0 O0 u 152,3034 366,5977 I 2! ,691 3 O, 5248933 6.791616 39 .~57~4 0.3390136 31,38792 6,317782 543,4246 0.5159115 22,30717 5,061245 75.86409 0,2533289 13.60577 6.109575 188.8215 3 · 2 7893 02 16,66368 3.322224 76,72823 0,~346950E-0t . .~042 4.181867 428.9644 0.2272838 14.13050 !.972152 86.4~504 0.9007913E-01 100.4223 2.532695 1127.486 1.880090 34.58205 2,419536 ~74 44~0969 18.56458 2.140~47 130.0919 0.1!93491 1 8. 00203 1.716088 2~0.5:~20 0.92321 2:~ E-0t 418.8347 739.7100 0.8758010 28.84180 458.3484 994,6143 1.338962 377.0789 589.3772 780.8140 I .020t72 t02.0287 43t,5146 1055,731 0,2969358 3~2~ .... q049 445,4Q39 1101.48~ I ,007144 48.34747 46~,3599 1080.581 1 .276179 406.0369 613,4385 1034,268 1,313657 7.367489 214,3894 1247.311 2.611381 ~1 9q065 496.3206 962.0154 1.403752 1 7t. 8573 534.1416 101 3, '34., ~' 0,9705664 34,4~6~2 29~.4043 I ! 35 ,~47 I .475703 11 .54975 9.9O90G! '4048.516 43.19910 203.2358 4 :~ 6'~803 4~4.5~$i I · 43,38~6 3.046537 970 540n 358 · I cq~ ~ 1~07.719 ~,. 029134 15738.0~0 31 .h3500 9.9~00t -=~ 1-~ 4 C, 5 53.56717 1'4 t0 1 51.0~6:2 363 ~5~ 9675 41 '~ ~4.1 5689 ~.330030 345.2771 0.1262422 50.35191 316·5010 977.t327 t ·096074 1 ~6~,~, 10.56~ 9. 5t77.19o 13635.000 ,3.Z0000,30 0.000003,3 3400 -55. 32707 5! .56~76 57.4461.8 14.39272 -61.65520 O.~OOO000 0.0000003 150·~51~ 365.2051 ~0.50069 t.93s703 0.0000000 · !J U J U U ~ ~ ~.n 00000~u~ ~.0©00000 26.83070 4.~6o765 243.9225 0,1390136 0.0000000 O.Ou~:uOuO 0.0000000 0.0000000 14.4i192 80.92563 !.0748o2 0.3000000 0.0000000 0.0o -10.00000 .~, ~,, .~ · -999.2500 -9~9.2500 -999.2560 -9a9.2500 -999.2500 -999.2500 -999,2500 -999 Psnn -999.2500 -909.2500 -99~,2500 -999.2500 -999,~500 -~90 ~5 -999,2500 -999,~500 -999,2500 -999,~500 -999,t500 13538.000 -999.2500 -999.2500 -999.~500 -999,~500 -999.2500 -9~9.2~80 -99~,2500 -999, ~¢00. ~ -999.2500 -999,~500 -9~9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -~99.2~0n -99'9.2500 -999 250~ TOTAL D.a, TA RECORDS ST~R~ING, , T~P=~ D~PTH,_ ~iLE TR~.ZLE~ **~* : 147 = 14388,.00 ENDING T.,~P E DEPTH = 1350.~ ~ 'o · 0 0 FILE ~ 3 HAIN .003 **** ~ILE HE~DER **** 1024 * CON~ENT RECORD * DATA IN S S&24PLES/FT. FORMAT RECORD (TYPE# 64) ONE DEPTd PEP FR.&ME TAP~ D:PTH UNmT : FT ~ CHT Aq 1 L~ 4 4 CN 6~ 1 oCT .4 5 HRD1 6~ 1 C~ ~ ,..j '~.~ 6 HRD2 5~ 1 CTS 4 7 SFT2 65 1 CT$ & ~ ~HR 68 1 DIM 4 ~ PE 68 I SARN ~ 0 PORZ ~8 1 mCT 4 1 SmD 68 ! PT/ 4 2 SSD 6~ 1 CTS 4 3 SSN 68 I CTS 4 4 LSN 65 1 CTS 4 5 ZCOR 5~ 1 GNCC 4 6 ZDEN 58 ! GMCC 4 ? TTEN 68 t LB 4 8 3EV 68 t OEO 4 0 qB 58 I DEG 4 D~T~ DEmTH H~Ol PORZ ZCOP (TYPE# CAL HRD2 SPO ZD~N O) GR SFT~ SSD TTEN CHT SHR SSN D E V PE LSN RB 14390.000 -999.2~0~ -9~9.2503 -9g9,~500 -99~.2580 -~99,2500 -909,2500 -9g9.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -99'~ 2:00 -g99.~500 -999.2500 -9~9,2500 -~99.2500 -999,2500 14377.500 985.8257 6.7e6682 O. 9239006E 7,673000 1257.394 11.9988.0 2.593778 O.O000000 ~77 28x. 1 9046.645 4116,660 227.0280 0.5140980 O. O0000u~,,, 41 .~0057 -15.00000 4.45453~ 0.0000000 56.95232 14365.000 983.7229 7.113904 $.'~031153E-01 7.675000 1~76.128 15.¢9840 2.588353 O.O000000 78~.42~5 ,'~ ~0~$. 1 ~5 422°.504 22~ 9264 0.5337989 362.9814 40.78821 7,5021~9 4.177486 227.0305 56.95232 1~352.50,3 1008.54S 6.32095°· 0.9928125E-01 7. 072866 1228.248 1 '~ 99~50 . . ~,,.~ 2.601~12 19.80074 786,4595 910! 8 · i :,,.., 524R.06* ~35,4487 361 ,6863 40.65508 7.437687 4 272~89 227.027~ 56.95341 14340.030 $m0.444~ -2.576704 0.190B771 8.397245 1061.061 14.99850 2.75~063 1Q.01620 65g.3853 9580.477 5o~,797 1519.122 0.4649211 360.7051 40 ~0084 7.3888~6 5.255651 227.0253 17.97716 14327.500 719.~294 4,0! 5635 3. 0328843E-04 8.671259 914.~076 14.99850 2.64133~, 18.95667 552.6624 7501 91m 5543.566 1217.394 0.4828832 444.7476 40.95813 3.050238 4.942721 373.5642 2.799699 14315.000 S.489944 14302.500, 732.8L~34 0.9175345 3. 5054827F--01 14290.000 795.8442 5.1253,66 0.23610ZaE-01 14277.500 658.7046 0.6S0059S 0.1~72411E-01 661 .0249 0.2936~69 O. 2505C50',=-01 14252,500 892,3330 7,771212 ~ P465~17E-01 14240,000 648,8164 1,742713 0,¢088619E-02 !4227.5u0 711 .299R 3.3021~5 0.1,~!4529E-01 14215.000 784.6636 8.198135 -~.,19o44~=-01 1 4292,500 998,2$10 a .791~32 3,2533164E-01 14190.000 ~3'9 ~,o, 6~ 4,734126 3. 2449652E-01 8.706251 903.5403 2.6503:23 390,9292 14,9°8513 2,694311 8.706623 1003,243 14,99850 2,622306 8.704!Z6 841.2334 14 2.69:~885 8,809374 836,1204 14,9~850 2,704979 8.73S066 1104.~73 14.99850 2.577113 8,70549:3 374,9656 1 4. 9985''~ ~, 6:502.01 8,80¢374 937,512S 1~,99850 2.653534 1 051 . .663 14.9 c, -" - r' i.56o613 ~ ox~4p4 1173,e74 14,99850 2.559663 5.S09374 o65,1172 14.~0850 2.62P047 17,'93167 5~7,~303 74~ 5,098 5555.82/-, 51,~9826 643.P349 7879,~05 560~,656 37,96889 642.3455 790~ 70TM , ~ 5469.57~ 27.45796 507.4314 7458.348 55~.145 14,57334 505,2817 7494,621 5628,910 25,33145 761,4963 8164,871 5555.250 28,3t10Z 519.,5Z98 7406,547 5~5p 711 13,71097 572,0481 7644,!52 5§Zl ,203 . . ~.,: ~., 5°5.,. 1 7599,582 1'3.9~4~,6 72~.5667 8270,902 56~7.750 1'5 4~21 . ~ ~ 686.1079 7851.555 -555~.164 115¢,718 0,4578211 435,8081 40,87801 1222,731 0,6228882 253,3233 41,09666 1095.030 200 u,5869 419,3374 40,83957 t104,99~ 0.4757570 519,4553 40,94316 1150,994 0,5054109 492,5737 40,82437 1098,240 9.64~6530 376,2319 41,03812 1136.787 0,5118139 491.3760 40,91S46 1116,108 0,4964961 462,75t7 40,98730 1134,680 0,5718240 320,3879 41,06462 1137.093 "' ~059t81 330.6453 41 1066,004 0,6554021 279.1182 41,1964~ 5.286825 5.203365 311.2148 3.05,s760 15.65326 3.150635 110.3477 2.3~6542 9,771166 3.5~6734 ~33,4454 2,914347 1,556578 5,003811 498,4541 3,064162 2,642571 4,583951 428,0081 ~ 4~Z136 ~ m ~,~ 10,81940 2,962083 199,4~04 2,629486 2,358012 4,4S$t10 3.521605 3,624277 4.711768 .371,5120 2,979390 !1,34048 3,~98~73 165,9399 2,505755 11.343S6 4,576267 17!.2Z70 2,560533 17,7964.0 ,.: ,846505 I I 2 73'7~ 4.304706 14177.500 861,2126 6,57471 5 O. 362284':~E-01 14165.080 933.6534 8.986897 O. 374,5~14F-01 141=' _.':Z · 500 973.2744 11.90~,,:~ 2 0.1072561E-01 14140.033 9~7.Z168 1 2.-P6943 0.1255'?SxE-01 1~127.500 783.6094 5.5 lr~X ", ~ 0, 25 41790E-01 14!15.000 123'5..1i5 t3.fi1094 O. 67701 £ 2E-01 14102.500 8~2.3430 3.953005 0.7330871E-01 $29.2036 7.658710 0.3783037E-01 140~7.500 101 9.558 1,_3.55890 0.3031810,1-01 14065.000 852.$145 7.16744? 0.3613456E-01 14052.5'30 ,815. 7 .'.95 '"'. ,,9. 2542749E-01 S.911118 1097,~0 14.9~$50 2 5~757'~ 9.323616 1223.201 14.99850 2,556325 9.531Z50 1299.347 14,99850 2,506360 ~.452187 1328.531 !4.9o850 2.500194 1751.392 14.9~S50 ~ ~15774 9.015625 1510.310 i · · - 2.4?8.964 9.049576 1102.~55 14.99850 2.~42405 9,402571 1151.370 14.~9850 2.578~66 9.118752 1234,775 14 998~0 2.529444 9.01=625~ 1151.399 14.99,~50 2.587438 9.015625 1053.070 1 4 908='0 1~,61~7 7~5.~ -, :$~11.14~ 5590.134 1'9.65602 719,7681 8460,242 15.0~!92 760.~-336 83~-~.691 5554.395 !4.49314 772.0300 84'3©.703 ~5,~7.o~ 17.05205 585,7~29 7964.8t 3 5~ ~7.11472 958.6?60 9376.934 5556.563 58,92046 668.7937 8478.953 5573,191 31.44888 701.8420 8337.832 5662.754 Z0.41640 825.2349 8512.199 5644.098 t0.72365 703,6457 8756.172 5630,621 1~,3323! 594.6182 'R ~'"" 3 541 5615,934 1098.845 0.4834340 4!.44505 10~,, 751 0.4~00210 3'27.2871 41.29971 t070.202 0.5161309 338.6218 41.33510 1140.40~ 0.4~9t/4.90 335 11~. 0 46500='..' 450.6636 41.14964 1077.172 0.6469079 Z02,2010 41,29950 1110,261 0.5147560 264,6475 41.30447 1091.936 0.5414021 403.3396 41.4~7 88 1097.781 0.5248780 380.5920 41.26790 t051.010 0.464~041 382.4258 41.37694 1108.714 0.4939511 443.2336 4!.48373 I0 ~151; 4.933523 173.8143 4.077652 11,993~9 164,7651 6.580746 t!,31305 4,42491~ 175.5966 12,16940 9.528639 4,~-339384 ~0~~ . 1544 m :,U ,,:' , 4.032639 ~ 2~4125 350,93t4 11.93876 34,.07461 52.60390 8.461267 14.26944 4.444905 121.4507 4.362790 7,835971 4,076216 247.0601 7.303919 10.28551 4.300230 2,06.7858 9.083157 8.326864 5.268685 Z28.~431 7.821682 5.499011 4.762087 312.2058 9.81¢411 14040.300 8,3=: 5.211297 ,3.37:5143¢E-01 14027.500 856.06:13 6.1 ?5365 0.4986777E-01 140tS.000 775.3797 3.4211900E-01 1400£.500 663.7e57 3.5319380 0.3448668E-01 13990.000 1512.506 16.57262 0.1012243 13977.5~0 ,805.6460 1.95664¢~ 0.9934324~-01 13965.000 7;0.160'o 4.3841o7 13952.~00 765.2271 4.584327 0.!779892E-01 13940.003 6.5091,55 0.2615910E-01 13927.500 705.051~ 2.508664 3. 20361~0~-01,~ 13915.000 8¢5.4673 8.406~6 3. 2556039~-01 9.015~25 1059.491 lZ,.99550 9.11375 2 1129.612 14, ,~850 2.605,~91 ~.015625 1024.$77 1 4 '99' 2.640765 9.015625 879.9688 14.99850 2.700905 10.7-5950 1817.340 14.99850 2.426609 9.118752 1083.327 13,998~0 ~.5'76542 8.81 776~, 9~8.0227 14.9~50 2.635032 ~,11~752 973. 336Z 14.99850., 2,631609 9.118752 1085.177 14.99850 2.593694 ~.015255 905.9578 14.~9850 ?.~103 9.005096 1157.10~ 14.9o850 2.5662~1 17.84441 ^~5.2166 81 04. 594 10.96308 6n1.0076 8357.977 5674.324 16.44482 6!1.1514 S054.738 56o4.613 13.55416 543.4338 7635.609 5491.848 110.58~8 !233.321 10274.02 5.897. 047 22,87939 697.2832 3656.5~7 '5663.113 30.19566 609.3193 7735.445 5 ~ ~.'? 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" .... =0,'3 -9o9.2500 -090 2500 -9°9. 2500 -999.2;00 -9:~9, ~., , ,. -999.2500 13640.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -990.2500 -999.2500 -999.2500 90.0 ~50n -~9o 2500 9~9 £.,uO -999 ~500 999.2500 -999.2500 136P7 =LqC -ge9 ~500 -~99 ?~00 -990 2503 -999 2500 -999.2500 -999'.~500 -909.~500 -999.2500 -999.2500 -999.~500 -99~,2500 -999.2500 -999,2500 -999.2500 -909,2500 1'~615,, .OGC. -99':~, ·2=nn~,..,.~., -999.2500 -999.~500 -o99, . -9~9,2500 -999,2500 -999. 2500 -999,2500 -999. 2500 -990. ~533 -099,250!]) -999,2503 -999· 2500 -999, -999.25~g 13602.5!30 -g9c~. , .25C0_ -99~:;?., .,_PcO0,,, -9'99.75"'""uu -0, 99. 2500, .... -999. 2500 -999 . 2500 -999,2500 -999,2:500 -099 · 2500 -999. 2500 -999.2500 -9'99 . 2'500 -999.2500 -9'79. ,;:? 500 -9~9.2500 I 3590,000 -09,o. 2500 -999,2500 -9'~9. 2500 -999. 2500 -999 2':;0!3 -909 ':.,~nr-) ,.-' -,~:nr' -c~99 ~0",,.3 -909 2SOO 9~.2~00 ¢oo "'~C -9~':~ ?500 -o9o '~500 -999 ;~nO ~ .,., ~ ~ ,., ~ ." ,..,. , ~ ~ ,,, . ,. ~ ~ . J ~ L~ ~,. -099.2~00 '-' 7. ~:; U' '3 - ~ o ,g. 2 ¢ C "'" -9 ~."" :."," 250 r- - 99 o "' ~. ~:""0 -70o·2.'560 -99° 2503 -99'?,. .... ,-' cc::~ <00 -9c~o psno -09'9 · ~, · ! :'.,. ;, r .. , m -9 O ,q'. .... , .......... . .... uO -,099.2500 -?'~9 2~0~ -9o~ ~2500 -9~o 2~00 -90,0 2500 -909 2500 ~ o99.2~00 -g~ 2500 -999 25n0 -g99 2500 15552.50(3 -909.2500 -990.~500 -999.2500 -999.2500 -909.~500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -99~.2500 -999,2500 -999.2500 -999.~505 -999.2500 TOT,~L DATA RECORDS S~aRTING TAPE OEPTH FILE TRAILER **** : 449 = 143~ '" ENnING TAmE DE PTH = 13550.00 FILE .# 6 MAiN .006 **** FiLE HEADER **** 1024 1 1 I t I 1 1 ! 1 1 1 1 1 1 t 1 1 1 U N i T ,5 Y T E $ 7' N "' H 4 ~CT CTS 4 ,,~ . CTS 4 DIM 4 DARN 4 ~CT 4 FT/ CTS CTS 4 CTS 4 GMCC 4 Gmcc 4 LB 4 OEG 4 D~G 4 DEPTH HRCl PORZ ZCOR RECORD (TYPE# C&L HRD2 ZDEN n) 966 BYTES * GR SFT? 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OC, O 961 .3,643 4.951351 0,10.g3735 13.24476 1202.569 15.59220 2,625333 100.5107 9097.227 5500.840 1148,767 0.6095179 Z07,4976 42,67192 27.t8221 3.285184 63,S0360 10,07195 13578,000 O.O000000 -15.00030 -0.1000000 0.0000000 0.0000003 2.000000 48.81596 a~O0000 4. ~.- · 0.0000000 4000.~00 500.0000 O.O00OO00 114.8001 0.0000000 62.50020 2,000000 21.8¢970 0,0000000 TOT,&L gAT& RECORDS STARTING TAPE DEPTH FILE TR&ILER **** : 139 = 14 37:~. O0 ~ NO --'. N~ TAPE DE=TH = 13550,00 FiLE # 7 R~PT .007 **** FZLE HEADER **** 1024 * COMMENT ,RECORD * DATa, IN 2 SAMPLES/FT. F ORM,~T RECORD (TY~E~ ONE DEPTH P=R FRAME T~P~ [~EPTH UNiT : FT E S A M (!;'4) PLE# dNiT t iN~'H 1 .~ I ! 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O0000 O 0000000 0.n000000 -0 100000~ -' · '. ~ ~. ~, . u 2.000000 ~400 O0n O. 000n000~, 13628.000 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -~99.2500 -99~.2500 -999.2500 -99~.2500 -999.2500 -999.2500 -099.7500 -999.2500 -999.2500 -999.£c~0~u 1357:~,,,,.000 -99~...P5OO,, -9-09~ .~.PSO0 -990..2500 -90,~..2500 -9~)9. 2500 -999. ?500 -999. 2500 -999. 2500 -099. ~500 999 2~0n -999 2c~ ~500 ..... ~uO -099 2500 -999 2500 -99~ ~ TOTAL O~TA RECORDS STARTING TAPE DEPTH ~ILE TRAILER **** - 111 : 1437B.00 =NDiNS T~PE DEPTH = t35~0 no =.rLE ~ n FiLE HE&DER **** 1024 * COMHENT RECORB * PLES/FT. FORMAT RECORD (TYPE# 64) ONE DFPTH PER =q'~,ME TAPE D~PTH UNZT : CURVES : NAME COD GR CHT 68 CN 68 SSN LSN 68 TTEN 68 r NC 68 E S~MP 1 1 1 1 1 I 1 1 LE# UNIT BYTES AP1 4 PCT 4 FT/ & ~T~ CTS ~ oCT ~ * DATA RECORD DEPTH SSN 13640.000 -909.~500 13590.000 t11.37~? 13540.000 114.2~$~, 134~0.000 , i 'L.~ .., i,.~ , 1:3440.000 131.4285 13390.000 145.8277 133~0.000 109.1893 13290.000 158.57~4 13240,0C0 146,~215 131~0,000 118.$&73 (TYPE# GR LSN -999 2~no -o9o., ~.~500 /~9,53351 19.58080 61 ,~ZOO~,. 23 7:821 . ~.; 30. 09496 77 7 g 5 "'-' _, . . U~ 27.72653 34. ~,/-,' ~'1 22.1761Z ~3.79791 53.50952 22,228C0 2t.66597 55,35890 31 .77688 43.36440 42.09300 27,73~50 O) 1014 5YTES * CHT TTffN -~9~.2500 -9~9.. ~5~''~.. 1042,693 5215,105 978.37~3 5219 23n 9~4,7195 5189,238 .~ . 5179,160 91 7. ,RS 28 918,9475 51 62,43~ 5156,e~6 5100 *~6 896.7617 5065.629 CNC -999,2500 -~9. ::'5 O0 66.60321 66.85614 54.64407 54.18994 46.0946-0 z, 5,57227 34,49431 34.22585 26.75027 26.942~0 47.26276 46 23.99~31 24.35756 30,62473 30,63257 ~,2.16028 41 .69226 29.99701 29.99701 30 I .~ ~0,7~111 29,9.~7~1 29,~9701 29,99701 30,~9690 31.65179 147. .363,5 43.28380 5n6~z~' ~,.2'~.. ~-:p443n- -~ 130~0.000,. _~2.c4~3~. :. ~9g~.313~, 23.8~845~ 30.a96~0. ., 147 · 544 2 48 · 90700 507:~. 660 ~:4 · 23Z5 4 1 3040. 000 23. ~5508 ~9:3.31 3Z 1 8. ~7578 30. 99690 174.6931 70.~n~.80 499~ ~3~ 19 77339 1 29~0. CO0 2Z, 65662 889. 8000 27, Z825~ 30. ~9690 136, ~21 7 39,5~781 4993. 738 27.41 400 1 2940. 030 ~. 27443 855,4~66 100,7692 30. 99690 96. 6361 I t 5.79340 4990. 297 105,0226 12890.00~ 1,.~c2.6100 ~.6506 ~- ,t6637. 30.99690 1 ~5 . 4 ~3~ 17,3~861 ~96~, 85 ~ ~ 5. 0475 v 1 2~40. ~0~ 71 ,662~9 ~69.9756 72. 50812 30. 99690 106 261~ ~9 3360~ 4~60.0Z7 7~ O03~m I 2790.00~ 85 . 90381 $79,75 27 60,1055~ 30. 99690 113.9254 21.661 21 69~1 , 594 59.82935 u~O00 12760.000 9o. 98473 ~O0..~q~qO 71 . ~2508, c,... O0~ 1 07.2C29 19.5~8~ 4000.000 71 . 85469 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 67 13640.00 ENDING TAPE DE PTH 12710.00 **** TaPE LIS 59108tl 3929 0t TRAILER **** TOTAL RECORDS iN THIS LOGICAL TAPE : 2359 **** REEL LiS 891'~,$112~ . ATLAS 01 TRAILER **** TOTAL RECORDS IN THIS LOGICAL PEEL : TOTAL RECORDS IN THIS PHYSICAL REEL: End of execut±on: Sat 2 SE° 89 7:11p E~apsed~ exmco~ion.. +ime· = Io, minutes. 44. .0_ $¥STEFI ~TURN CO.'D~ = O 2360