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Home My WebLink About198-0357. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU NWE2-01 Renew Well Suspension Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-035 50-029-22866-00-00 ADL 0047446 9815 Conductor Surface Intermediate Production Liner 9175 80 2632 9248 9005 20" 13-3/8" 9-5/8" 8373 32 - 112 32 - 2664 28 - 9276 32 - 112 32 - 2664 28 - 8640 None 520 2260 4760 9005 1530 5020 6870 No Perforations 3-1/2" 9.3# L-80 26 - 2125N/A Structural No Packer No SSSV Installed Date: Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com (907) 564 4891 Prudhoe Bay 10/27/2025 Current Pools: Borealis Oil Proposed Pools: Borealis Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-634 By Gavin Gluyas at 9:04 am, Oct 16, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.16 05:59:10 - 08'00' Torin Roschinger (4662) J.Lau 10/23/25 06/30/28 A.Dewhurst 22OCT25 10-404 Other Conditions of Approval: Well must be fully plug and abandoned by 06/30/28 including an approved 10-403 for abandonment by 12/31/27 or Have approved justification of future utility approved by 12/31/27. Post Initial Injection MIT Req'd? Yes No DSR-10/22/25 10/23/25 Hilcorp North Slope, LLC Torin Roschinger, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 10/13/2025 Commissioners Jessie Chmielowski, Greg Wilson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Field, Borealis Oil Pool, NWE2-01 (PTD #198035) Application for Renewal of Existing Suspension (10-403) Dear Commissioner Chmielowski and Commissioner Wilson, An AOGCC witnessed suspended well inspection of Borealis well NWE2-01 was conducted on 07/04/2025 (20 AAC 25.110 (h)). The 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: Suspended Well Site Inspection form documenting the site condition. Wellbore diagram illustrating the current configuration of the well. Borealis well NWE2-01 was suspended on 04/22/1998 and has future utility as an exploration well tied to O-pad and I-pad development. The strata through which the well was drilled is neither abnormally geopressured nor depleted. The well is secured with unperforated casing and a cement plug in the open hole section and extending into the casing. The well is mechanically sound as proven by a passing pressure test of the casing to 3600 psi on 4/15/1998, after the casing was run and a tag of the top of the cement plug. Based on these conditions and the inspection on 07/04/2025, Borealis well NWE2-01 meets the provisions required in 20 AAC 25.110 (a)(1). Hilcorp North Slope, LLC 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, Hilcorp believes Borealis well NWE2-01 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 406-570-9630 or Oliver Sternicki at 907-564-4891. Sincerely, Torin Roschinger PBW Operations Manager Attachments Technical Justification 2025 Suspended Well Site Inspection Form Wellbore Schematic Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.16 05:59:44 - 08'00' Torin Roschinger (4662) Borealis Well NWE2-01 (PTD #198035) Technical Justification for Renewal of Suspended Status 10/13/2025 Well History and Status Borealis well NWE2-01 (PTD #199035) was suspended on 04/22/1998 after drilling to TD and logging. The well was drilled from an ice pad adjacent to the Milne Point access road to better understand the resource potential in the western part of the Prudhoe Bay unit. The well is secured with a cement plug within the open hole section and extending into the 9.625 casing with a TOC at 9005. The well is mechanically sound as proven by a passing pressure test of the 9.625 casing to 3600 psi on 04/15/1998, after the casing was run and a tag of the top of the cement plug. 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 nor depleted. Condition of the Wellhead and Surface Location Borealis well NWE2-01 is not located on a pad and is situated approximately 220 east of the Milne Point access road on the tundra. The surrounding area is in good condition. There is no discoloration and no sheens around the well or on nearby water. The well pressure readings T/I/O= 38 psi/ 1psi/ Not accessible Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for NWE2-01. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 InspectNo:susGDC250706203443 Well Pressures (psi): Date Inspected:7/4/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:10/4/2001 #300-033 Tubing:382 IA:14 OA: Operator:Hilcorp North Slope, LLC Operator Rep:Andy Ogg Date AOGCC Notified:6/27/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UN BORE 02-01 Permit Number:1980350 Wellhead Condition Master valve only on wellhead. The well looks to be in decent shape for having no protection from the elements showing surface rust with no signs of leakage. Surrounding Surface Condition The area around the cellar had standing water that was clear with no signs of hydrocarbons or debris. Condition of Cellar Clean water present with no signs of hydrocarbons or debris. The cellar is covered with heavy timbers and has a well guard on top of the timbers to protect the wellhead. Comments Well location verified by map. Supervisor Comments Photos (8); Sundry 300-033 was for Ops Shutdown and subsequent letter dated 10/4/2001 converted well to Suspended Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, August 5, 2025          jbr 2025-0704_Suspend_PBU_Borealis_2-01_photos_gc Page 1 of 4 Suspended Well Inspection – PBU Borealis 2-01 PTD 1980350 AOGCC Inspection Rpt # susGDC250706203443 Photos by AOGCC Inspector G. Cook 7/4/2025 2025-0704_Suspend_PBU_Borealis_2-01_photos_gc Page 2 of 4 Ground water around cellar box 2025-0704_Suspend_PBU_Borealis_2-01_photos_gc Page 3 of 4 Well cellar 2025-0704_Suspend_PBU_Borealis_2-01_photos_gc Page 4 of 4 Tubing pressure gauge IA pressure gauge NWE2-01 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-035 50-029-22866-00-00 9815 9175 80 2632 9248 9005 20" 13-3/8" 9-5/8" 8373 32 - 112 32 - 2664 28 - 9276 32 - 112 32 - 2664 28 - 8640 None None 1530 5020 6870 No Perforations 3-1/2" 9.3# L-80 26 - 2125 N/A No Packer No Packer Torin Roschinger Operations Manager Andrew Ogg andrew.ogg@hilcorp.com 907.659.5102 Prudhoe Bay, Borealis Oil ADL 0047446 26 - 2125 N/A N/A 0 0 0 0 0 0 0 1 34 38 N/A Borealis Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.07.10 12:47:13 - 08'00' Torin Roschinger (4662) By Grace Christianson at 7:32 am, Jul 11, 2025 JJL 7/21/25 DSR-7/21/25 RBDMS JSB 071725 NWE2-01 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:198-035 6.API Number:50-029-22866-00-00 Prudhoe Bay, Borealis Oil Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0047446 Property Designation (Lease Number):10. 8. NWE2-01 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 5 Development Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9815 Effective Depth MD: L-80 11. 10/13/2020 Commission Representative: 15. Suspended 5 Contact Name: Oliver Sternicki Contact Email: oliver.sternicki@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager 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): 9175 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend 5 Plug for Redrill Perforate Perforate New Pool No Packer No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 32 - 2664 32 - 2664 14. Estimated Date for Commencing Operations: BOP Sketch 32 - 112 Structural 6870 Proposal Summary 13. Well Class after proposed work: No Packer None None 3-1/2" 9.3#26 - 2125 Production 9005 8373 9005 none 32 - 112 520 13-3/8" 9-5/8" Contact Phone:(907)564-4891 Date: 4760 80 153020"Conductor 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 2632 5020 Intermediate 9248 28 - 9276 28 - 8640 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 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 9:11 am, Oct 14, 2020 320-438 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.10.13 16:24:11 - 08'00' Stan Golis Suspension Renewal Expires December 31, 2025. DSR-11/2/2020 X DLB10/14/2020MGR15OCT20 Yestion Required? Comm. 11/2/2020 dts 11/2/2020 JLC 11/2/2020 RBDMS HEW 11/12/2020 Prudhoe Bay Field, Borealis Oil Pool NWE2-01(PTD #198035) Technical Justification for Renewal of Suspended Status October 13, 2020 Well History and Status Borealis well NWE2-01 (PTD #199035) was suspended on 04/22/1998 after drilling to TD and logging. The well was drilled from an ice pad adjacent to the Milne Point road to better understand the resource potential in the western part of the Prudhoe Bay unit. The well is secured with a cement plug within the open hole section and extending into the 9- 5/8” casing with a TOC at 9005’. The well is mechanically sound as proven by a pressure test after the 9-5/8” casing was run and a tag of the top of cement. 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 Borealis well NWE2-01 was drilled from an ice pad and has no gravel pad or pits at the location. There is no discoloration and no sheens near the well, or in nearby water. The well pressure readings are T/I/O = 34/ 0/ NA psi. Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for NWE2-01. 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. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:198-035 6.50-029-22866-00-00 Prudhoe Bay, Borealis Oil Hilcorp North Slope, LLC 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 9815 9005 8373 none none 9005 none Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32 - 112 32 - 112 1530 520 Surface 2632 13-3/8" 32 - 2664 32 - 2664 5020 2260 Intermediate 9248 9-5/8" 28 - 9276 28 - 8640 6870 4760 Production Perforation Depth: Measured depth: None feet True vertical depth: None feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# L-80 26 - 2125 26 - 2125 Packers and SSSV (type, measured and true vertical depth) None Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 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: Andy Ogg PBFieldWellIntegrity@hilcorp.co Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907-659-5102 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory 5 Development 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 measured9175 Sundry Number or N/A if C.O. Exempt: No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Inspect Suspended Well Operations shutdown Change Approved Program 5 N/A 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: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 047446 NWE2-01 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 m By Samantha Carlisle at 8:53 am, Aug 19, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.19 08:43:39 - 08'00' Stan Golis RBDMS HEW 8/19/2020 SFD 8/19/2020MGR02SEP2020DSR-8/20/2020 ACTIVITY DATE SUMMARY 8/2/2020 T/I/O = 34/0/NA per AOGCC rep. Suspended well inspection by AOGCC rep Matt Herrera. Daily Report of Well Operations PBU NWE2-01 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:NWE2-01 Field/Pool: Prudhoe Bay / Borealis Oil Permit # (PTD):1980350 API Number: Operator:Hilcorp North Slope LLC Date Suspended: 4/22/1998 Surface Location:Section: 19 Twsp: 12N Range: 11E Nearest active pad or road:MPS Pad / MP Access Road 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: Good. Pad or location surface: Good. Location cleanup needed: No. Pits condition: N/A. Surrounding area condition: Good. Water/fluids on pad: Non pad. Discoloration, Sheens on pad, pits or water: None. Samples taken: None Access road condition: Milne acces road in good condition. Photographs taken (# and description): No. 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: Tree - master valve. Wellhead - TBG spool with 2 casing valves, starting head with 1 casing valve. Cellar description, condition, fluids: Snow/ice melt. Clean water. Fluid in cellar below lowermost casing valve. Rat Hole: N/A. Wellhouse or protective barriers: Yes, guard. Well identification sign: Yes. Tubing Pressure (or casing if no tubing): 34 psi. Annulus pressures: IA / OA = 0 psi / N/A Wellhead Photos taken (# and description): Yes. (1) sign and wellhead/tree. Work Required: None Operator Rep (name and signature):Eric Dickerman AOGCC Inspector: Matt Herrera Other Observers: Inspection Date: 8/2/2020 AOGCC Notice Date: 7/31/2020 Time of arrival: 8:30am Time of Departure: 8:50am Site access method: Truck/Walk. 50029228660000 Re-Inspection ' Suspended Well—Inspection Review Report |nspectNo: susK8FH200804090522 Date Inspected: 8/I/2020 ' Inspector: Matt Herrera - | Type ofInspection � Well Name: _ ) PRUDHOEBAYUN8ORE0Z�)l Permit Number: ------ | 1980350 - � Suspension Approval: Completion Report - Suspension Date: | 10/4/2001 ' | Location Verified? W |fVerified, How? , ! Other (specify incomments)Offshore? El �Subsequent - � Date AOG[[Notified: 7/3I/2020 - Operator: Hi|co/pNorth Slope, LLC Operator Rep: E/ic0ckerman Wellbore Diagn*mAvai|7 Photos Taken? Well Pressuns(psi): Tub34 F|uid in Cellar? A. O BPV|nstoUed? [] �� [] DA� VRP|ug(S)Installed? Wellhead Condition Access on tundra by foot. Well head seemed in good operating condition, Valves operational. No gauges installed but fitted for digital gauge. No access to OA valve maybe possible in winter when ground around cellar is frozen. [ondbionofCellar [eUarculvertarnundweUheadiscovene6vvith4"u12''woodenp|ankswbhnouccessto0AVake.Thereiswate/ ' surrounding the outer cellar culvert approx 3-4Ft deep. Water inside cellar culvert approx 3ft below OA flange connection. Water inand out ofcellar culvert clean with novisible sheen. SunoundingSurface Condition � Novisible stains ortuod/avegetation compromised. ~ Comments Location Verified by Aerial Photo Map. Operator informed to update well sign information (company name; API number). Supervisor Comments Photos (3)include corrections onwell sign (API # and "Opeotor"). � �zo/ Monday, August 17,2U2O Suspended Well Inspection — PBU Borealis 02-01 PTD 1980350 AOGCC Inspection # susMFH2O0804090522 Photos by AOGCC Inspector M. Herrera 8/2/2020 A.tl S�Ni 9BE i " Ai 2020-0802_Suspend_PBU_Borealis _ 02-01 _photos_mh. docx Page 1 of 2 WELL NAME NWE2-01 OWNER Prudhoe Bay Unit T--- OPERATOR liilrorp North Slope, LLC. ! �� SUR. LOCATION SE 1/4, Sec. 19, Tt N, R11E DRILLINC PERIVIT 98-35 API Number 50-029-22866-00-00 Corrected well sign — Operator and API # 2020-0802_Suspend_PBU_Borealis _ 02-01 _photos_mh.docx Page 2 of 2 • SMITE DT ALASEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Gary Preble V i Date Management Engineer �A BP Exploration (Alaska), Inc. e" P.O. Box 196612 A �`� Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Borealis Oil Pool, NWE2 -01 Sundry Number: 310 -407 Dear Mr. Preble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this,' day of January, 2011. Encl. • .� STATE OF ALASKA C �( \' ALASK L AND GAS CONSERVATION COMMISSI� V APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ . Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: RENEW SUSPENSION - ISI 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory 0. 198 -0350 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22866 -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: NWE2 -01 - Spacing Exception Required? Yes ❑ No CI 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO - 047446 . PRUDHOE BAY Field / BOREALIS 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): 9815 9175.4 ® 9005 8372 SURFACE TOC NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE 110 SURFACE 110 1490 470 Surface 2626 13- 3/8 "68# L -80 32 2664 32 2664 4930 2270 Intermediate 9248 9 -5/8" 47# L -80 28 9276 28 8640 6870 4760 • Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE - - 3 -1/2" 9.3# L -80 iURFACI 2125 Packers and SSSV Tvoe: NONE Packers and SSSV MD and TVD (ft): 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch p Exploratory 0 ' Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/21/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ., 61 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature )� Phone Date �,. 564 -4944 12/7/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 0 — L t a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: If 1tcrr't Pty / /W'.m 4- -,1 J p.s� zO AAC— Z Alaska S . ��d C � �� / � / D (� E C Gas 0 9 X 2 / 0 � 0 Subsequent Form Required: Ajp.a, h, pi' 1 " I "`' Cons. G0111f1113�q� 6 Anchor e APPROVED BY i Approved by: ` COMMISSIONER THE COMMISSION Date: l DI1AA5 JAN 06 20 /z• /o•% „% r' - -/-*/ /d Form 10-403 Revised 1/2010 R 1 6 1 N A Submit in Duplicate • • • Prudhoe Bay Unit well Bore 2-01 Technical Justification for Application for Renewal of Suspension Status December 03, 2010 Well Status PBU Bore 2 -01 (PTD 1980350) was suspended on 04/22/98 after drilling to TD and logging. The well was drilled from an ice pad adjacent to the Milne Point road to better understand the resource potential in the western part of the Prudhoe Bay Unit. BP Exploration (Alaska), Inc. (BPXA) completed a suspended well inspection of PBU Bore 2- 01 on 09/22/10. The results of that inspection were submitted with a Report of Sundry Well Operations (form 10 -404) on 10/06/10. The well is secured with a cement plug within the open hole section and extending into the casing. The well is mechanically sound as proven by a pressure test after the casing was run and a tag of the top of the cement plug. 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. A final development strategy has not been determined for this area. The well has potential ,_ -r future utility for surveillance, a pilot study or inclusion in a small satellite pad. , Condition of the Wellhead and Surface Location Having been drilled from an ice pad, PBU Bore 2 -01 is not located on a gravel pad and there are no pits at the location. There is no discoloration near the well site or in nearby water. The current well pressure readings are T /I /O = VacNacNac.✓ Request BPXA requests approval for renewal of the existing suspension status for PBU Bore 2 -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. MLB 12/03/10 -. • I NWE 2 -01 Suspension Program Depths are listed as MD/T'VDrlcb i AI ' , ... ' _ Casing 20" Conductor Casin r3 110' /110' ?tl r Cement to surface T. : e:, r ;: _:! • , :, iesei to 2000'md in 13 -3/8" x 9 -5/8" annulus and within 7' .r %F.: 1. • "-" a 3 : 2091' of 3 -1/2" tubing stinger , A 13 -3/8", 68 #/tt, L -80 Surf Csg 0 2664'/ 2664' '" • Cement to surface 4. s ilm illirklimil :" Top of Stage 2 Cement (13.1 ppg) -. r 0 2664'/2664' M 71 ES Cementer Located 0 7418'/6918' Top of Stage 1 Cement 15.8 ppg 0 8276'/7688' fe Cement Tagged - , at 9005'md K weight •' M 1- G k. v 1 rx •' x;3 9 -5/8 ", 47 #/ft, L -80 NSCC Csg ®9276'md'/8640' • 's;3te• . '" '_'-- -_ • Sag Top ® ;: 1 9326'md VZ :1,t.: 1 �g . I S ". " . ' S . St3. TD at 981579174' STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other ❑� INSPECT Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver[ Time Extension ❑ WELL Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑� � 198 -0350 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 ` 50- 029 - 22866 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 047446 NWE2 -01 10. Field /Pool(s): PRUDHOE BAY FIELD / BOREALIS POOL 11. Present Well Condition Summary: Total Depth measured 9815 feet Plugs (measured) SURFACE TOC feet true vertical 9175. feet Junk (measured) None feet Effective Depth measured 9005 feet Packer (measured) true vertical 83 72 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110 1490 470 Surface 2626 13 -3/8" 68# L -80 32 - 2664 32 - 2664 4930 2270 Intermediate 9248 9 -5/8" 47# L -80 28 - 9276 28 - 8640 6870 4760 Production Liner Liner W WS) N0V 2 Perforation depth: Measured depth: NONE - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 SURFACE - 2125 SURFACE - 2125 Packers and SSSV (type, measured and true vertical depth) NONE Vft 12. Stimulation or cement squeeze summary: Intervals treated (measured): OCT €) 7 2010 Treatment descriptions including volumes used and final pressure:U67��N11Ni. ° Wpm 13. Representative Daily Average Production or Injection a a Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑2 evelopment ❑ Service ❑ Daily Report of Well Operations X 16. Well Status after SUSPENDED Oil Gas Lj WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564 -4944 Date ��l l 0 A-- 801311 ii t 61 Y_ /o •Z'?/o • Prudhoe Bay Unit Bore 02 -01, PTD 1980350 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU Bore 02 -01 on 9/22/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector John Crisp witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • There are no wells with surface locations within one - quarter mile radius of the surface location. • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU Bore 02 -01 was suspended on QQ2/98 after drilling to TD and logging. • PBU Bore 02 -01 was drilled from an ice pad adjacent to the Milne Point road. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with a cement plug within the open hole section and extending into the casing. • The well is mechanically sound as proven by a pressure test after the casing was run and a tag of the top of the cement plug. MLB 09/24/10 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UN BORE 02 -01 Field /Pool: PRUDHOE BAY / BOREALIS Permit # (PTD): 198 -035 API Number: 50029228660000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 4/22/1998 Surface Location: Section: 19 Twsp: 12N Range: 11E Nearest active pad or road: MPS 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: Good Pad or location surface: Good Location cleanup needed: None Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Cellar Discoloration, Sheens on pad, pits or water: None / Froze Samples taken: None Access road condition: N/A Photographs taken (# and description): 4; wellhead; cellar Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: FMC; wellhead valves function good Cellar description, condition, fluids: Water / froze Rat Hole: N/A Wellhouse or protective barriers: Yes Well identification sign: Yes Tubing Pressure (or casing if no tubing): Vac / Annulus pressures: IA = Vac / OA = Vac Wellhead Photos taken (# and description): 4; wellhead; cellar Work Required: None Operator Rep (name and signature): Jerry Muphy 9 AOGCC Inspector: John Crisp Other Observers: R n t Inspection Date: 9/22/2010 AOGCC Notice Date: /20/2010 Time of arrival: 9:15 AM Time of Departure: 9:30 AM Site access method: Drive / Walk B m q� 1 � w o W I W U Q� VICINITY MAP N.T.S. N 5987000 4 RP #2 (500.66') 0 NWE2 -01 O 4 ICE PAD LIMITS AREA= 207,500 S.F. 4.76 ACRES RP# (194.55') ° ° °o ° °° °° ° ° ° ° ° °° ° °o ° °° 1 1 NWE2 -11 DRILL RIG OUTLINE °-'AR' °, TEPHEN STOLL 6726 -S OWL N 5986 0 N1NE2 -01 m SURVEYOR'S CERTIFICATE L)IU I HEREBY CERTIFY THAT I AM Ld N N P ROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 11, 1998. NOTES 1. DATE OF SURVEY: FEBRUARY 11, 1998. LEGEN 2. REFERENCE FIELD BOOK: EXP98 -01 (PG. 31 -33). 3. GPS DOWNLOAD FILE: NWE- 2— ALL.TXT 4. ALASKA STATE PLANE COORDINATES + AS —BUILT CONDUCTOR ARE ZONE 4, ALASKA, NAD27. 5. HORIZONTAL /VERTICAL CONTROL IS BASED ON Q RP TO WELL CONDUCTOR MPU K —PAD MONUMENT K -3. 6. ELEVATIONS ARE' BASED ON BPX MPU M.S.L. DATUM. O CORNER MARKER (8" SPIKE W /RED CHASER) 7. MEAN PAD SCALE FACTOR IS 0.99990576. LOCATED WITHIN PROTRACTED SEC. 19, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. GEODETIC GEODETIC GRND /ICE SECTION NO. COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS NWE2 -01 Y= 5,986,606.05 70'22'25.420" 70.3737278' 41.9/43.0' 454' FSL X= 570,682.31 149'25'31.738" 149.4254828' 284' FEL F. Robert DRAW dAC08S CHEO<ED: 1AacLEMM :• BP EXPLORATION p DATE: 2/12/98 DRAwINC: NWE2 -98 SHEET: JOB ND: NORTHWEST EILEEN 2 ICE PAD W�UULho AS —BUILT CONDUCTOR 18. 981SSIIED FOR INFORMAUON . -SS ILOH I SCALE: •"•® "E 1' =200' WELL NWE2 -01 1 OF 1 NO.. DATE REVISION 8Y CFtlC a.aaux. �+ NWE 2 -01 Suspension Program Depths are listed as MD/rVDrkb i 20" Conductor Casing 0 110' / 110' Cement to surface t :.. besel to 2000 m in 13 -3/8" x 9 -5/8" annulus and within 7" 2091' of 3 -1/2" tubing stinger > r 13 -318 ", 68 #Ift, L -80 Surf Csg @ 26647 2664' Cement to surface Top of Stage 2 Cement (13.1 ppg) v: 0 266472664' ES Cementer Located ® 741876918' Top of Stage 1 Cement 15.8 ppg 0 827677688' Cement Tagged at 9005'md w /20K weight w"°s I #;"s' ::. c ;+• "' 9 -5/8 ", 47#/ft, L -80 NSCC Csg @9276'md'/8640' Sag Top ® ti . 9326'md .. t . TD at 9815'/9174' Air �. 4 jj 3� ��- �� '+ �* t � � � � n: WELL NAME NWE VaA OWNER Prudhoe Bay Unit OPERAT100e' BP Exploration SUR. LOCATION SE 1/4, Sec. '19, T1 N, 811E DR/LL/NC PERMIT 98 -35 q . s • � l t Wr S � 4r 7 » $`` ^ t4 LL NAME NWE 2MO1 ;J 1 � r A� OWE ± 's Prudhoe BOY Unit PE BP Explpration SUR. LAS SE 1/4, Sec. 19, T1 K R11E RILLINC PERIVIT 98-35 �I i n ------------ -. . ) ~~!Æ~! ':J !Æ:!Æ~~~!Æ í ALASIiA OIL AND GAS / CONSERVATION COMMISSION / ') l. TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 October 4, 2001 Gordon Pospisil, Team Leader BP Exploration (Alaska) Inc. West End New Developments PO Box 196612 Anchorage AK 99519 Re: Wells NWE 1-01A, NWE 1-02 and NWE 2-01 Dear Mr. Pospisil: Enclosed please find 3 Applications for Sundry Approval to extend operation shutdown for each of the above referenced wells until April 2002 that we are returning to you because the current status of each of these wells makes these sundry applications unnecessary. Well Completion Reports have been filed for wells NWE 1-01A and NWE 1-02. Therefore, the status for those two wells is shut-in and they should be included with the shut in wells list required by 20 AAC 25.115. A Well Completion Report has also been filed for Well NWE 2-01. Our records also reflect that the well has a downhole cement plug covering the reservoir interval and extending up in to the casing. The well is filled with 9.6ppg mud to the base of pennafrost and has diesel freeze protection to surface. Our records reflect that the well has never been flow tested and is not in pressure communication with the reservoir. Although the well does not have a near surface plug as required by 20 AAC 25.110(d), the well condition satisfies the requirements of 20 AAC 25.112(i) because it provides for at least equally effective prevention of fluid movement into sources of hydrocarbons or freshwater. The Commission will, therefore consider the well suspended. If you have any additional questions, please contact Tom Maunder or Bob Crandall at the above telephone number. Sincerely, .~y ~~~t~ C~chsli Taylor Chair bp ) ) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 March 1, 200 1 Commissioner Julie Heusser Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 994501 Re: Extension of Operation Shutdown NWE 2-01, Prudhoe Bay Field Dear Commissioner Heusser: Please find the attached request (Form 10-403 Application for Sundry Approval) to extend operation shutdown for well NWE 2-01 until April 2002. The request is submitted in accordance with the requirements of 20 AAC 25.072. If you need additional information, please contact Bruce W. Smith at 564-5093. NWE 2-01 is an appraisal well drilled from an ice pad in the western portion of the Prudhoe Bay Unit in early 1998. The well was left in a mechanically safe condition which would allow us either to resume further testing or to complete the well for development operations. One year operation shutdown was approved in April 1998 and extended in May 1999 and February 2000. Since the drilling of this well, the owners have made progress in evaluating the drilling results and in the potential development for the area. The owners are currently engaged in a conceptual engineering effort to better define pad and pipeline requirements for the area. Recently, gravel has been laid out to wells NWE 1-01A and NWE 1-02. The gravel road will allow drilling and testing year-round, not just during whiter ice season. Extension of the operations shutdown for NWE 2-01 will preserve additional appraisal, testing and/or development options at this location. Sincerely, IZ (' . ~~ LV /~ ,f:.... Goydo-. fos f;~U Gordon Pospisil, Team Leader West End New Developments RECEiVED GPlbws Enclosures (3) Cc: Bruce W. Smith MAR 1 2 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL , STATE OF ALASKA ALASKA ì AND GAS CONSERVATION CC ~ISSION APPLICATION FOR SUNDRY APPROVAL Is-., J~7J 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging D Time Extension D Perforate D Alter Casing D Repair Well 0 Pull Tubing D Variance 0 Other o Change Approved Program IZI Operation Shutdown 0 Re-Enter Suspended Well D Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surlace 453' NSL, 4553' EWL, SEC. 19, T12N, R 11 E, UM At top of productive interval 2175' NSL, 146' EWL, SEC. 20, T12N, R11 E, UM At effective depth 2642' NSL, 435' EWL, SEC. 20, T12N, R11 E At total depth 2625' NSL, 860' EWL, SEC. 20, T12N, R11 E, UM 12. Present well condition summary 5. Type of well: D Development rzI Exploratory D Stratigraphic D Service Casing Structural Conductor Surlace Intermediate Production Liner Size Total depth: measured true vertical Effective depth: measured true vertical 9815 feet Plugs (measured) 9175 feet 9005 feet Junk (measured) 8372 feet Length 110' 2626' 9248' 20" 260 sx A tic Swt (Approx.) 133/8" 1404 ~~.... ol~se' III, 473 sx Class'G' 95/8" 4:0 J~~\o5\0 sx Clæs 'G' )~ ~. "û\ 3 1/2", 9.3#, L-80 to 2115' Perloration depth: measured N/A true vertical NI A 13. Attachments rzI Descripf n summary of proposal 14. Estimated date for com encing operation April 0 ,2001 to April 01, 2002 16. If proposal was ver lIy approved D Detailed operations program 15. Status of well classifications as: 6. Datum Elevation (OF or K KBE = 74.06 7. Unit or Property Na Prudhoe Bay Unit 8. Well Number WE 2-01 9. Permit mber 98-35 98-071 10. AP umber - 029-22866 . Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool MD TVD 110' 110' 2664' 2664' 9276' 8640' RECEIVED MAR 1 2 2001 Alaska Oil & Gas Cons. Commission Anchorage D BOP sketch DGas o Suspended rzlOil Service Date approved Prepared By Name/Number: Scott LaVoie, 564-4636 Bruce W. Smith 564-5093 17. I hereby ce fy that the fore.. going is t:r;¡u and correct to the best of my knowledge Signed 1/2 " I ~ -U Title Senior Petroleum Engineer Commission Use Only Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 06/15/88 OR'G\¡\~¡'~\L Date "3/12.(0 I I Approval No. :?01- o5S- ~~~tJ.\ t..'\.~~~ ""\ - C)':).. Commissioner Date Submit In Triplicate ) ) NWE 2-01 Sundry Status: Operation Shutdown Original Date of Sundry Approval: 4/22/98 Post Drilling Status: · Well is fully drilled, cased and cemented. · Well does not have any open perforations. · A complete wellhead and Christmas tree is in place, tested and operational. A backpressure valve has been set and tested in the wellhead receptacle. The wellhead and Christmas tree were tested to 5000 psi. · Well has 2125 feet of 3 Y2" 9.3#, L-80 tubing installed. · A cement plug was placed in the 9 5/8 inch tubing from a TD of 9815 MD to a cement top of 9005 MD. The cement top was tagged at 9005'MD. The 9 5/8" casing shoe is located at 9276' MD. · The well has 9.6 ppg KCI drilling mud from 2091 ft to PBTD of 9005 MD in the tubing, annulus and remaining casing. The well was freeze protected with 2091 ft of diesel in the tubing and annulus. · Open hole logs show no Kuparuk Formation potential in this wellbore. · There is SAG / Ivishak formation potential. · Open hole logs were interpreted with 37 ft of net pay in the Sag River Formation and 46 feet of net pay in the Ivishak Formation. · The well was cored in both the Sag River and Kuparuk Formations. · A MDT was run and measured an oil sample of 38 degree API. · The top of the cement plug in the 9 5/8" casing, located at 9005 MD, is 318 ft above the top of the Sag River Formation allowing re-entry and further completion and testing. Current Status: Well is being observed on a regular basis. Borealis Field is being developed in the Kuparuk Formation to the SE. Borealis wells are also being logged and evaluated in the Schrader Bluff Formation. Request: Extend Shut Down of Operation Status to April 2002 Tentative Plans: Continue monitoring of well during flyovers. Log Borealis Field wells in the Schrader Bluff Formation for reservoir evaluation. Review and update well plans with AOGCC by April 2002. RECEIVED MAR 1 2 2001 Alaska Oil & Gas Cons. Commission Anchorage ~ \ Cement Tagged at 900S'md w/20K weight Sag Top @ 9326'md ') ') NWE 2-01' Suspension Program Depths are listed as MDflVDrkb l ~t:~ii ,;'~':':', ':~ ~ ¡lIltl :~¢:;~~ '" . ({.~~ ~~IC 20" Conductor Casing @ 110' /110' t.~", ; ," ',' . ~~ ;g Cement to surface ~~~.~;. ~~-: 2 ' j ... i.. : ~iesel to 2OOO'md in 13-318" x 9-5/8' annulus and within 7" ; I U 2091' of 3-112" tubing stinger :( 13-3C:::~ :;~uL~SUrf Csg @ 2664'/2664' Ii~ .., Ii :1: '. i Top of Stage 2 Cement (13.1 ppg) ¡ ~~: @ 2664'/2664' .......:.~ ... '1:" ð· .., L' ....... ;0.. r ~.I ~ ? ES Cementer Located @ 7418'/6918' i . ;m~ ~ ~ ~I'~~ -. " ,:¡ ..... .~".."."..:-. ..t ...~. . "" 0° ~ '.." .. . ~....~. ".....,.c. ~...e..~. . -:. Ålil': .-... ';:g-n..... '. ~~1J!f£ ' I···..··..·~ ".,.-..... ¡I1li: g ^-,.....' ,..-.... Q::;; :·?i~::;'~W; :.;~~. Top of Stage 1 Cement 15.8 ppg @ 8276'n688' SP CONFiDENTiAL 9-518", 47#/ft, L-80 NSCC Csg @9276'md'/8640' RECEIVED TD at 9815'/9174' MAR 1 2 2001 Alaska Oil & Gas Cons. Commission Anchorage Borealis Pre-PA Application Meeting, February Jj, 2001 -I I I Prudhbet~ I ¡I: 1 - : - - - - -- - - -- - - - --- -.!-- - - --- - - - - - - - - - - - ~ - -- - - - - - - - - - - - --+- - - - - - - -- - - -- - - - - i - - -- -- : i ! ¡ ; ¡o ¡ : i : ! ! ! ¡ : : i ! : i -- - -. -- - - --- - - - -- ~-- - - - - - -- - - -- - - - - - +- - - - - - - - - -- - - -- - + -- -- - -- - - - - - - - - -- + - --... i ¡ ! ! ! ! ~EECHEY_PT_S·rl2.- ! i i I I I ¡ i BEECHÈY_PT_ST_1ff ¡ PBU Boun~ary ¡ -~ I I I I I I I I I I I I I I r I I I --- --- ----- ---... -- ¡--- -- --...- -- --- --Î---... ----------...... r-.........- --... ---- --.. ---~--..... --------.. --...- ; ! i ! ! : I I I I ; : I I I I I I : : : : _ ¡ Ii ___.___m_::!~~~~~:..-- ' - ¡ ¡ NW_ een...l" ! i - -I I I I : I ________________ --+----------------- I I I I I I I I I I I I I I : : I I 1 I I I I I I I I I I I = -+--... --........ -- -----... -+ --- -- --- --...... --... I I I I I I I I I I I I I I I I I I ~ I I I I I I ¡ ¡ lLSAIL1 == -t- - -- - - --- --- --- --t- - _u - - -- -- m --t- - _m .- ---- - __n : ! i ! i I I I ¡ ¡----------------- 1 1 I I I I I I I I I I I I I I I ... -- -- ...--............ -- ----1-- --... -- --- --...... -- -- +-............... --...... -- --...-- NwLL02lil ¡ ¡~¡ I I : : : I 1 I I ____1_-= ~_~~ ~___ _~ __ _ _ _ __ __ _ ___ -----Ì- _ __ __ _ _ _ _ _ __ ___ _ _ +_ _ __ _ _ __ _ _ _ _ - - - -- ... : ! i t ! ! ! i ! lLxuP_:L1Lll ¡ ! ¡ I ! : 1________ ________j__________________ I I I I I I I I I I . I ProposediPA Bound~ I ----------------i----------------- i----· : r ! i : I : : : : I I I I ! ! - -- - - - - -- - - - -- - -~ - - - - - - - - - - - - - - - - -.;.. --- I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I 1 I 1 I I I - - - - - - - - - - - - - -- - ~ - - -- - - -- - - -- - --- - - ~ -- -. I I I I _ 1 I I I I I i : I 1 I I I I I I I I I I I I : : - ---1mA---------------:--_· : I I I I I ¡ ¡ -.0 i ! i - ( i i z-oe.: I I --------:=~:--1,--- 0-030 ~~l---------":~F I I I I I - - -- ï - -- - - -¡- - - - -1 i - - z:'- i ã õ - - ï - ~t - -- -1- - - - - - -1- - - - -- +-. ,~, I I I 1 1 I 1 1 I 1 I I I I 1 I I I I 1 1 I I - ---- -- - - - -- - - -- -,--- - -- -- - - ---- --- t- ------------ -- -- t --- -- -- - - -- ------ I I 1 I I I 1 I I I I I I I I I 1 I I I I : ; ; I I I I I I ! ¡ i ¡ I I I -T------r~-----T------T----h------r-----It---_¡- -----¡------,-----,-----,---TI------,-----I - - Z-35. IILIIImII, . . 11~r'. . ¡"IIILIIIIZ'IØI ITRTUTE NILD~ :. .\ :\ ~ 1..1TII1\/Œ NILD OGross Isopach OIlly .Gross Isopach and Reservoir Properties DCore in Kupafuk _ .........-uu.w... t Attachment 8. Well SummlgY. - Borealis P A and Regional Wells used for Isopach and Properties Mapping BOREAL I S F I EL1D1. WELL DATA -a. ...' ... I ...- I I ) "\ :) __________,__ __··,_···"_______..______·_·,·,··____·_,___·___·____r___...________.__,.__.._.....,._._._._______.,._._._.________...__._ ..-.---"'---.-,-----------..-.-.,---------.-.--.--.".--._--~--."''''_._--_._----_.,."'..~_.._-----_._-_.._-,-,_._.-_._..__._._---_.._._-_._.__._.~_._-,.__.__. _______.._,....____. _·_·_·_.._____..__,·____·_'"_.....___.._.__·_·_,._._u___._."__.._'__"__"'___'.'__."... --.-.--.--'---,..--.-".--., ---..,--...,.--------., '.". -~ --.--..'''''--''''-'-''--''- "'--"-~'-'---------~'~--'-----'- Well Compliance Report File on Left folder 198-035-0 PRZE BAY UN NWE 02-01 50- 029-22866-00 BP EXPLORATION clVÍÍ> _º-21t5_ TVD -º2JI~_ ompletion Date: .__~1¿~2/~~_ Completed Status: I-OIL Current: .~,-,---_._-- T Name Interval Sent Received T/C/D --------,----------- L BRP 2658-7442 OH 2 6/8/98 6/9/98 L CMR 2L 266405176 OR 5 6/8/98 6/9/98 L CST INAL 3660-4750 OR 6/8/98 6/9/98 L DGR/CNP/SLD-MD ~L 9280-9815 OR 6/2/98 6/3/98 L DGR/CNP/SLD-TVD vINAL 8643-9175 OR 6/2/98 6/3/98 L DGR/EWR4-MD AAL 110-9815 OR 6/2/98 6/3/98 L DGR/EWR4-TVD 4AL 100-9175 OH 6/2/98 6/3/98 L DSSI ~AL 2658-7382 OH 6/8/98 6/9/98 4AL I L ENG. LOG-MD BL 110-9815 ~-' OR 1 5/1/98 5/4/98 L FMS & OR LOGS-MD ~. BL(e) GRlAIT/PEX POR/FMS OR 5 6/30/98 7/2/98 L FMS W /DIPS vr BL(C) 6185-7460 OR 5 6/30/98 7/2/98 L MDT FINAL BL(e) 9332-9734 OH 6/8/98 6/9/98 ~AL .~ L MUD-MD BL 110-9815 ~ OR 1 5/1/98 5/4/98 L PEX-3DD/CN t.-¥1ÑAL 2658-7442 OR 6/8/98 6/9/98 L PEX-AIT ~AL 2658-7452 OH 6/8/98 6/9/98 L PEX-CN ~AL 2658-7429 OH 6/8/98 6/9/98 L PEX-MCFL ~AL 2658-7442 OR 6/8/98 6/9/98 ( L SSTVD ~AL 2658-7452 OH 6/8/98 6/9/98 R DIPMTR EV AL ~'SCHLUM 7285-7295 OH 6/30/98 7/2/98 R FMS / BL(e) 6200-7450 OH 2 6/30/98 7/2/98 R SONIC EV AL ~. SL(C) 2658-7382 W/DSI OH 1 6/30/98 7/2/98 R SRVY RPT ~' SPERRY 0-9815. OR 6/3/98 6/5/98 D T 8502 / SCHLUM PEX-AIT/DSI/FMI OR 6/8/98 6/9/98 T 8505 VIO SPERRY MPT/GRlEWRlCNP OH 6/2/98 6/3/98 ---.--.-.-----'. .._--------,-- -- ----,_._-_._-------,~-- ---'-~----'-'- ------- ~.__.-_._----_._---,-,._-,-_._-,-- -----..-.-------...------.,-,--.-------- ---_._~-,_._.__._--_._-' ._-.._,._,~-,_._~.".._- .,,-,--_.._--..---. ---...--.---..-.--,.-------,,---- _.-,.- - --...- ..-- -______0___-__-,-·---,·-------------------·----·· ---,_._-_.~-'--._-_._- "'--',--- .---,-_.,---_. ,--,_.-.,----,--_.,---_._---- ---.- Monday, May 01, 2000 Page I of2 Daily Well Ops Was the well core~9ß(L Comments: ) ) Are Dry Ditch Samples Required? yes no Analysis ~tioi:)ReceiVed? yes no t) k.:..~ And Received? (V;¡J ng, Sample Set # . .-Ì--o.Lg_..- --'--~-'-'"----"---'" .--.-- ---.-,---.--..---.-.--." --.--.--.-------.----.-"'-....-.-.-.- -----.--.-.-".,----- _.,-~".._.._.~" ..--.------.---.-- --..-------.....--------,,---.-...---....---------..-----._-----~--_..~-_._._---_._-----'.---_..._."'_._.__._..-.,-..------,...----.------.--- ---.---.---- ._--_._---_..._-----"_.._-------,.".~._,._.__.._.,_.._.----. --'~9 ----' ~, \", , . ' ß \/1' ~,'-... ðV\o(J è.AJ (¡V "I 1~ ~ t{)l· ----- -------.-. -_.._'._._,_.,~,-"-_.._._--_..__..-.-. .,.....--.-.-... -..-,,-.. ,~_.__._- ·..·7 6;-) , \ /' \,'--..---.... '~~ \i.~ ~ S\:\\~t~ ~ ,(~\ )J 0-- .. \fP'\ ( /1 -,' ~ ell ') (,I'I ..l.;, l.) , ",~k~'c J" v\ \¡, ~ "J ./ -0 vI L \ ----,--.-"'---. ._~----_.._..- - - -- -.--_._--- ----.-.-----.---- .-------- --.--.-.------..--.-"""-------- ----------..--"..-. --.----------.-.,-.------ - ---- .-----.--.--- - ----~,--,--_.__._,--_._-----------'-- -",----.--. -----,-,-----~-----,._._---_._---_._---,--,------'--,.-_.._,----"------,,--,-,,,-- 0-_____..---,..- __~_ ..._._._ _ .,__.___..._,_,_,_ ____., 0._ ..'__,___ .._.__ _ Page 2 of 2 - --,----,----- -"'--'-'---'~'-"'-'---"- Monday, May 0 1, 2000 ) I ') ~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 IBP CONF~DENTIAL January 28, 2000 Commissioner Robert Christenson Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Extension of Operation Shutdowns NWE 1-01A, 1-02,2-01 Prudhoe Bay Field Dear Commissioner Christenson: Please find the attached requests (Forms 10-403 Application For Sundry Approval) to extend operation shutdowns for another year (until April 2001) on wells NWE 1-01A, 1- 02, and 2-01. The requests are submitted in accordance with the requirements of 20 AAC 25.072. If you need additional information, please contact Bill Smalstig (ArGo) at 263-4319 or Steve Deck.ert (BPXA) at 564-4128. NWE 1-01A, 1-02, and 2-01 were appraisal wells drilled from ice pads in the western portion of the Prudhoe Bay Unit during the period of January through April 1998. The wells were left in a mechanically safe condition which would allow us to resume either further testing or development completion operations. One year operation shutdowns were granted in April 1998 and extended in May 1999. Since the drilling of the wells, the NWE owners have made significant progress in evaluating the drilling results of these wells and potential development for the area. Consequently, Arco has filed for gravel permits and has plans to lay gravel out to wells NWE 1-01A and NWE 1-02 during the spring of this year. The gravel road will allow drilling and testing 12 months of the year, not just during winter ice season. The owners of these Kuparuk wells are working with the IPA, NWE Schrader Bluff, and PBU Schrader Bluff Owners to progress a consensus Western Region development plan. These owners are currently engaged in a conceptual engineering effort to better define pad and pipeline requirements for the area. Extension of the operations shutdowns for NWE 1-01A, 1-02, and 2-01 is necessary to preserve additional appraisal, testing and/or development options at these locations. ~incerely, I. "'. ~ '"t:- + ÍM ~ Joe Hurliman, Team Leader Central North Slope Asset - Western Developments BPXA J H/sld Enclosures (3) RECEIVED FEa C 2 2000 Alaska Oil & Gas Co " _ A ch no). Commission n Grage ) STATE OF ALASKA ) ALASKk OIL AND GAS CONSERVATION CUlvlMISSION APPLICATION FOR SUNDRY APPROVAL kt)- "\, CONFIDENTIAL Co 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging IZI Time Extension 0 Perforate o Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other o Change Approved Program IZI Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' NSL, 4553' EWL, SEC. 19, T12N, R11E, UM At top of productive interval 2175' NSL, 146' EWL, SEC. 20, T12N, R11 E, UM At effective depth 2642' NSL,435' EWL,SEC.20,T12N,R11E At total depth 2625' NSL, 860' EWL, SEC. 20, T12N, R11 E, UM 12. Present well condition summary 5. Type of well: D Development IZI Exploratory D Stratigraphic D Service 6. Datum Elevation (DF or KB) KBE = 74.06' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NWE 2-01 9. Permit Number 98-35/398-071 10. API Number 50- 029-22866 11. Field and Pool Prudhoe Bay Field / Kuparuk River Oil Pool & Prudhoe Bay Pool Total depth: measured 9815 feet Plugs (measured) true vertical 9175 feet Effective depth: measured 9005 feet Junk (measured) true vertical 8372 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 2626' 13-3/8" 1404 sx Coldset III, 473 sx Class 'G' 2664' 2664' Intermediate 9248' 9-5/8" 430 sx Class 'G', 1500 sx Class 'G' 9276' 8640' Production Liner true vertical NI A D/(I I G/f¡¡ 3-1/2",9.3#, L-80 to 2125' ,'4 ¿ 8P CONFfDENT'i~L Perforation depth: measured NIA 13. Attachments IZI Description summary of proposal 14. Estimated date for commencing operation January 01, 2001 to April 01, 2001 16. If proposal was verbally approved D Detailed operations program RECEIVED FES G2 2000 Alasl<a all & Gas Cons. Commission Anchorage D BOP sketch Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) NIA 15. Status of well classifications as: IZIOil DGas D Suspended Name of approver Date approved Contact Engineer Name/Number: Steve Deckert 564-4128 Service Prepared By Name/Number: Bill Smalstig, 263-4319 17. I hereby certify that th 3 foregoing i;) true and correct to the best of my knowledge Signed ----. {. Joe Hurliman ~ ~... ~ Title Team Leader Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 1 0- Y\.O~ ~\\C~ c'"' ~~ \J~S\-~, (¿:. ~ ~ "'~ '\e:. '" "' ç ~ o...c.... ~'\....;) \ .\.'1 '\ ~ \ \we. c-... ~ aò Go9} I. Approved by order of the Commission ~RlbGcrtINANLCSII~NED BY ,~,)'pro~\1\'neó): Commissioner Date;.... /0 ·...a 1\0 . Inslt::r)~ou f\ß\. J"¡ U . .. Form 10-403 Rev. 06/15/88 _0.-.~~' Submit In Triplicate Date I 2~ ðb I '7 ó'1/I 'Î"7 ..;;J Approval No,: JU.l-L.',J J ') ) NWE 2-01 Sundry Status: Operation Shutdown Original date Sundry approved: 4/22/98 Extension of Shutdown approved: 5/6/99 ~1J>..:t. \\'<W!,;""""~i!\~~\1'~~ /?, ~ t~~ :~r~;í~:q"'1<Ui~,]·'~ :~ti~¡),. l,.,t ¡ '';;'¡'' \:;¡J." ~ ';¡:r J/ Ø" -- ~ ;,; ~ Post Drilling Status: · The well is fully cased and cemented but does not have perforations in the 9- 5/8" casing string. · All surface equipment is installed, a back pressure valve has been set. The tree was pressure tested to 5000 psi. · The well has 2125 ft of tubing. Cement PBTD in the 9-5/8" casing is at 9005'md; 9-5/8" casing shoe at 9276'md. · The well has 9.6 ppg KCL drilling mud from 2091 ft to PBTD and diesel from surface to 2091 ft (both tubing and Inner Annulus). · The OR logs indicate there is no Kuparuk zone potential in the well. · There is production potential in the Sag/Ivishak horizons. · The well was cored in both the Kuparuk and the Sag River formations. · OR logs indicated 37 ft of net pay in Sag River and 46 ft of net pay in Ivishak. · An MDT oil sample in the Sag indicated 38 API oil. · The top of the cement plug in the 9-5/8" casing is 318' above the top of the Sag River formation. which means the well could easily be re-entered and completed/tested. Current Status: · Pad location not yet finalized. Need to drill another appraisal well to determine optimum location. Request/Way forward: · Extend Shut Down of Operations status. · Continue monitoring wells during Otter flights. · Review/Update tentative well plans with AOGCC by April, 2001. Tentative Plans* Plans to drill 1 additional appraisal well off ICE Potential testing of NWE 2-01 *Funding of plans has not yet been obtained by partners. Date 1Q/2001 ~ 1 Q/200 1~ #~ ~-$ ~ ~ <'~; ~ ô> /t.. (f()J C~ ~ ~~~ 0,-, ~ ~ ~ VCJ ~·c ~ ~ ~. ~¿; ~ Cement Tagged at 9005'md w/20K weight Sag Top @ 9326'md ,tt }.~ _,,,I IC,',..' NWE 2-01' Suspension Program Depths Bre listed as MDffVDrkb j ~~?¡¡~Jj ,:;~\~.: 1 ;~~ ff-ì ¡:I' .... ~III ~1 ~~ . è 20' Conductor Casing @ 110' /110' ~ ~ ;g Cement to surface ~ ~, Ii il. ! ~jesel to 2OOO'md in 13-318' x 9-~ annulus and within 7' I U 2091' of 3-1l2'tubing stinger I" 13-:~~ ::~u~:~SUrf Csg @ 2664'/2664' di I:: 1== I Top of Stage 2 Cement (13.1 ppg) j~~il @ 2664'/2664' .. ~ v. . . u 'D ^ (") , 10. . "..{ ES Cementer Located @ 7418'/6918' ,c (J I, I: S· ß{j:~E~\~~;'~;~YI,1 " ..... .... ~·ì. ,.."'...."'. .:-:...... Â¡'II ~.._....,. a ,..-...... ~lrI,11~t ( ,".."." -" ,..-...... ~ .~;; : ·;~i·~::::$:?:~~~;~; : .;¿.~.~.~ J Top of Stage 1 Cement 15.8 ppg @ 8276'fi688' , 0.. 3-'·~ '-Y" ~'1i"'~A' "L BP C 'f'\!~"štn~~s~~ H ' 9-5/8", 47#/ft, L-80 NSCC Csg @9276'md'/8640' I?FtEI1/£D [:£8 4./asI(aO//& C¿ êOOO 4 ~a8 COna. n Chl)t¡¡ . 1.10111111' qp lSSlon TD at 9815'/9174' ~ -) STATE OF ALASKA) ALAS,...~ OIL AND GAS CONSERVATION lJ~)MMISSION APPLICATION FOR SUNDRY APPROVAL v:a Co CONFIDENTIAL 1. Type of Request: D Abandon D Suspend D Plugging IZI Time Extension D Perforate D Alter Casing D Repair Well D Pull Tubing D Variance D Other D Change Approved Program IZI Operation Shutdown D Re-Enter Suspended Well D Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4531 NSL, 45531 EWL, SEC. 19, T12N, R11 E, UM At top of productive interval 21751 NSL, 1461 EWL, SEC. 20, T12N, R11 E, UM At effective depth 26421 NSL,4351 EWL,SEC.20,T12N,R11E At total depth 26251 NSL,,8601 EWLI S§C. 20, T12N1 R11,E, UM , 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of well: o Development ~ Exploratory o Stratigraphic D Service 6. Datum Elevation (OF or KB) KBE = 74.061 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NWE 2-01 9. Permit Number 98-35 I 398-071 10. API Number 50-029-22866 11. Field and Pool Prudhoe Bay Field I Kuparuk River Oil Pool & Prud,hoe Bay Pool 9815 feet Plugs (measured) ORIG\NAL 9175 feet 9005 feet Junk (measured) 8372 feet Length Size Cemented MD TVD 1101 20" 260 sx Arcticset (Approx.) 1101 1101 26261 13-3/811 1404 sx Coldset 111,473 sx Class IG1 26641 26641 92481 9-5/8" 430 sx Class 'G1, 1500 sx Class 'G1 9276' 86401 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured N/A true vertical NI A RECEIVED APR 2 3 1999 AIasIëa OR & Gas Cons. Commi&tIon Anchorage BP CONFIDENTIAL Tubing (size, grade, and measured depth) 3-1/2",9.3#, L-80 to 21251 Contact Engineer Name/Number: Steve Deckert 564-4128 / 17. I ~erebY certify that~he egO~J.lSl tnie ant co, rrect to the best of my knowledge Signed / ~··-I/ 1/ . Joe Hurlim~ñ-I ~::"\...T I i1/L"L.v\....-...-.__,. Title Team Leader Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test Subsequent fom1J:'Muired 10- "fJ~1 - ð Covr .,."Ie tj ".(,' {\eð. 0 . r..e\ù'< I ./ ~ \ ~'.:3- Packers and SSSV (type and measured depth) N/A 13. Attachments ~ Description summary of proposal 14. Estimated date for commencing operation April 22, 2000 16. If proposal was verbally approved Name of approver Date approved Approved by order of the CommissiolDRJGINAL SIGNED OY Form 10-403 Rev. 06/15/88 Robert N. Christenson o Detailed operations program o BOP sketch 15. Status of well classifications as: ~Oil DGas D Suspended Service Prepared By Name/Number: Bill Smalstig, 263-4319 , / II,...", Date Lf / / (/ { ? () I Approval N061~ ~ 78 Commissioner DateS-t -7 Ý Submit In Triplicate ) NWE 2-01 Suspension Program Depths are listed as MDITVDrkb j ·1;~f}"T.':.. .Ii :;:~~~c:~~;:ing @ 110' /110' . :' -~ ,~,: ,'~' ,:',~,. ,,<:: . ,:~~tt i>iesel to 2000'md in 13-3/8" x 9-5/8" annulus and within 7" ,,'::~ ',/.' :.,):~~,'~ ,),~~~: ::;~; 11/11111111 a2091 , of 3-1/2" tubing stinger I" ,,':':':.' '. :.:.:.:.:.: -r.~~'" 13-3/8", 68 #Ift, L-80 Surf Csg @ 2664'/2664' Cement to su rface :iæ: :::;.,;;¡, I¡; i Top of Stage 2 Cement(13.1 ppg) @ 2664'/2664' ~ '0 '-' () (Q A. () I ~ ES Cementer Located @ 7418'/6918' <. LJ ~0~ .~~, I: :¡it Cement Tagged ..g., ~t.:g~~~~ht . '. ..... ·····.·1 LUf\M;1~j." ~~ ~ ~:'."'-, ::'::":'Ø):" '~;"':'.:::'::' ...... ~::~~ aU ;:t;¡r'1_~!~;\~\', I .",¡" '" g:::j:¡~~~v!i1 Q(,~ Top of Stage 1 Cement 15.8 ppg @ 8276'/7688' 9-5/8", 47#/ft, L-80 NSCC Csg @9276'md'/8640' BP CONFIDENTIAL TD at 9815'/9174' 'I, ) \ NWE 2-01 Sundry Status: Operation Shutdown Date Sundry approved: 4/22/98 Current Status: · The well is fully cased and cemented but does not have perforations in the 9- 5/8" casing string. · All surface equipment is installed, a back pressure valve has been set. The tree was pressure tested to 5000 psi. · The well has 2125 ft of tubing. Cement PBTD in the 9-5/8" casing is at 9005'md; 9-5/8" casing shoe at 9276'md. · The well has 9.6 ppg KCL drilling mud from 2091 ft to PBTD and diesel from surface to 2091 ft (both tubing and Inner Annulus). · The OH logs indicate there is no Kuparuk zone potential in the well. · There is production potential in the Sag/Ivishak horizons. · The well was cored in both the Kuparuk and the Sag River formations. · OH logs indicated 37ft of net pay in the Sag River and 46 ft of net pay in the Ivishak. · An MDT oil sample in the Sag indicated 38 API oil. · The top of the cement plug in the 9-5/8" casing is 318' above the top of the Sag River formation which means the well could easily be re-entered and completed/tested. Request/Way forward: · Extend Shut Down of Operations status. · Continue monitoring wells during Otter flights. · Review/Update tentative well plans with AOGCC by April, 2000. Tentative Plans* Evaluate well/future pad utility Potential testing of NWE 2-01 Date 4Q/1999 1 Q/2000 *Funding of plans has not yet been obtained by partners. BP COr~FIDENTIAL ) , ') ," ~' ') BP EXPLORATION, Alaska <:,L,jJjgrrj[Uri1l:tM'; Date: Trans# 06-30-98 89220 NW EILEEN LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Rec Type Rec Date Comments OH 21-Mar-98 DIPOLE SONIC - RECOMPUTED ~,...,(eN t.)/ R~+ OH 21-Mar-98 FMIINTERPRETATION - HAND PICKED DIPS (60" = ;00') OH 21-Mar-98 CMR TOTAL POROSITY OH 21-Mar-98 CMR TOTAL POROSITYI FMI REP 21-Mar-98 SONIC EVALUATION WITH DIPOLE SONIC TOOL - BOUND REPORT 02-Apr-98 SONIC EVALUATION WITH DIPOLE SONIC TOOL - BOUND REPORT 03-Apr-98 FMIIMAGES MSD & HAND PICKED DIPS (FMI PASS/GR/CRC) 03-Apr-98 FMIIMAGES - MSD (FMI PASS / GR/CRC) 03-Apr-98 FMI AND OPEN HOLE LOGS - COMPOSITE DISPLAY (FMII PEX/AIT) 30-Mar-98 DSI- SONIC REPROCESS '5-\~ ~ -~e.~<,..r 21-Apr-98 DIPMETER EVALUATION SHEET L1-ß' ~6?- Sw Name Log Type 1JWE1-02 DSI -ilWE1-02 FMS ¡"~E1-02 CMR IijwE1-02 CMR /ÑWE1-02 DSI -./ 9"6' o~5 ~WE2-01 DSI -NWE2-01 FMS "ÑWE2:'01 FMS ~WE2;'01 FMS ~E2-01 DSI OH ~ .ÆJWE2-01 DIPMETE OH R "Î .lNWE1-02 DIPMETE OH qß· ob~ R REP OH OH OH 08-Apr-98 DIPMETER EVALUATION SHEET Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips - Paul Robertson DNR - Tim Ryherd AOGCC - Howard Oakland BP - Brett Chambers ()~ . ,_\II" Ii ..-. .:....,... jtL 02 (qCf~ . . ··::,:.:,:';~C:; Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 ) STATE OF ALASKA f If'" t'"" r" ~ " i ~... 11"'\ ALASKA OIL AND GAS CONSERVATION COMMISSION !!: \l~ tÒ~Fù!>Et¡T~ WELL COMPLETION OR RECOMPLETION REPORT AND LO~:_.Ji'¡ 1 G 1998 1. Status of Well Classification of Service Well rz¡ Oil 0 Gas 0 Suspended 0 Abandoned 0 Service:u;;:ski on 81 n::1S: r,nn~. Gnmmis3ion 2. Name of Operator 7. Permit Number ÞnCiìOrage BP Exploration (Alaska) Inc. 98-35 1398-071 398-071/084/101 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22866 4. ¡~~~~~~f:5e~3~t~,c;EC.19, T12N, R11E, UM ¡ëö:~ÏDÑ ~ 9. ~~~~~~~e~:~~~:re Attop of productive interval f _ <I ( J). i "lY \ ' ~ I 10. Well Number ~; ~~;a~:e~t~ 46' EWL, SEC. 20, T12N, R11 E, U M ,~IED ì ~~ ,,;,~~:.:j 11. Field and Pool NWE 2-01 2625' NSL, 860' EWL, SEC. 20, T12N, R11E, UM 11.-.,;-.."......... ...,..~ 5. Elevation in feet (indicate KB, OF, etc.) 16. Lease Designation and Serial NO... KBE = 74.06' ADL 047446 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. '15. Water depth, if offshore 16. No. of Completions 3/10/98 4/18/98 4/22/98 ./ NI A MSL One 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9815 9175 Fr 9005 8372 Fr rz¡ Yes 0 No NIA MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, RES I AIT, DT I BHC, CNL, LDL, GR, Caliper, SP, MRES, CMR, AIT, FMI, MDT, Dipole Sonic, Sidewall Cores 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 2011 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 13-3/8" 68# L-80 32' 2664' 16" 1404 sx Coldset III, 473 sx Class 'G' 9-5/8" 47# L-80 28' 9276' 12-1/4" 430 sx Class 'G', 1500 sx Class 'G' ) Prudhoe Bay Field / Kuparuk River Oil Pool & Prudhoe Bay Pool AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) None 25. SIZE 3-1/2",9.3#, L-80 TUBING RECORD DEPTH SET (MD) 2125' PACKER SET (MD) NIA MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 9005' - 9815' AMOUNT & KIND OF MATERIAL USED 65 Bbls Class 'G' Balanced Cement Plug Freeze protect with 149 Bbls of Diesel OR 'GINI-, 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) NIA (This well is in Operation Shutdown Status) PRODUCTION FOR OIL -BBL GAs-MCF WATER-BBL TEST PERIOD Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CHOKE SIZE GAS-OIL RATIO OIL -BBL GAs-MCF WATER-BBL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Marker Name K-5 K-2 Top HRZ Base HRZ / Kalubik K-1 Kuparuk D Kuparuk C Kuparuk B/LCU Kuparuk A Miluveach (Base Kuparuk) JKU/Kingak TJF TJE TJD TJC TJB TSGR TSHU TElL TSAD TZ3 Geologic Markers Measured Depth 5834 6612 6626 6729 6798 6900 6970 7049 7227 7319 7803 8047 8588 8706 9078 9139 9323 9372 9532 9570 9737 ) True Vertical Depth 5451 6149 6162 6261 6327 6424 6492 6568 6739 6826 7271 7486 7973 8084 8444 8505 8687 8735 8894 8932 9098 31. List of Attachments Summary of Daily Drilling Reports, Surveys ), 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time ~f each phase. See Attached 32. I ~ereby certify th~he foregoing is tr~~ and correct to the best of my knowledge Signed <.::--/_~. __~. ~ Dan Stone Title En~ineering Supervisor NWE 2-01 98-35/ 398-071/084 Prepared By Name/Number: Well Number Permit No. / Approval No. ".!".jQ3 Date Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 · ) ) NWE 2-01 GEOLOGICAL MARKßJ.i SUMMARY MARKER Measured True Vertical True Vertical Depth Depth Subsea Depth (feet) (feet) (feet) Permafrost 1743 1669 1743 T-3 / SV-l 2273 2199 2273 K-15/Ugnu 2563 2489 2563 WS-2 4038 3921 3995 WS-l 4312 4154 4228 K-12 I Seabee 4610 4399 4473 K-I0 5164 4846 4920 K-5 5834 5377 5451 K-2 6612 6075 6149 Top HRZ 6626 6088 6162 Base HRZ / Kalubik 6729 6187 6261 K-l 6798 6253 6327 Kuparuk D 6900 6350 6424 Kuparuk C 6970 6418 6492 Kuparuk B/LCU 7049 6494 6568 Kuparuk A 7227 6665 6739 Miluveach (Base Kuparuk) 7319 6752 6826 IKU/Kingak 7803 7197 7271 TIF 8047 7412 7486 TIE 8588 7899 7973 TID 8706 8010 8084 TIC 9078 8370 8444 TIB 9139 8431 8505 TSGR 9323 8613 8687 TSHU 9372 8661 8735 TElL 9532 8820 8894 TSAD 9570 8858 8932 TZ3 9737 9024 9098 TDD 9815 9101 9175 NWE 2-01 MDT SUMMARY RFT TEST - FILE # (Formation) 5-14 (Sag River) 6-15 (Sag River) 10-19 (Sag River) 11-21 (Eileen) 12-22 (Ivishak) 13-23 (Ivishak) 14-24 (Ivishak) 15-25 (Ivishak) 16-26 (Ivishak) 17-27 (Ivishak) 18-28 (Ivishak) 19-29 (Ivishak) 20-30 (Ivishak) 21-31 (Ivishak) Measured True Vertical Formation Pressure Test Type Depth Depth Subsea Pressure Gradient (feet) (feet) (PSIG) (psi/ft) 9340 8629 4165 0.483 Volumetric Pretest 9347 8636 4139 0.479 Volumetric Pretest 9345 8634 4135 0.479 Normal Pretest/Samples 9562 8849 4208 0.476 Slow Build 9585 8872 4155 0.468 Normal Pretest 9589 8876 4156 0.468 Normal Pretest 9589 8876 4156 0.468 Normal Pretest/Samples 9617 8904 4162 0.467 Normal Pretest 9622 8909 4164 0.467 Normal Pretest 9643 8930 4171 0.467 Normal Pretest/Sample 9668 8955 4182 0.467 Normal Pretest 9686 8972 4189 0.467 Normal Pretest 9718 9004 4203 0.467 Normal Pretest 9734 9020 4210 0.467 Normal Pretest MDT Sample @ 9345' md (Sag River) recovered 38.5 API Gravity oil MDT Sample @ 9589' md (upper Ivishak, 2-4B) recovered 31.7 API gravity oil Page 1 NWE 2-01 CORE SUMMARY ) ') Core #1 Core #2 Core #3 Start Depth End Depth Cut (feet) (feet) (feet) Kuparuk C/B 7034 7066 32 Kuparuk B 7066 7095 29 Kingak/Sag/Sl 9301 9392 91 * See Attached Core Chip Sample Descriptions Core depths in measured depth Recovered (feet) 26.5 28.5 91.8 NWE 2-01 SIDEWALL CORE SUMMARY SWC's Shot UgnulWsak sidewaUcore samples from 4737' to 3660' md on April 3, 1998 Attempted 30 SWC, Recovered 27, Left 3 shots in the hole. Had 1 misrun * See Attached Core Labs SWC Analysis Report SWC Sample # Sample Rec. Depth (ft) API Oil Gravity Description 1 1.2 3660 13 Oily Sd 2 1.8 3667 Gray Sd 3 1.5 3694 14 Oily Sd 4 1.6 3697 Gray Sd 5 1.6 3795 12 Oily Sd 6 1.0 3805 12 Oily Sd 7 1.1 3955 14 Oily Sd 8 1.0 3970 14 Oily Sd 9 1.5 4004 17 Oily Sd 10 1.5 4022 Gray Sd 11 1.6 4076 19 Oily Sd 12 1.6 4085 20 Oily Sd 13 0.6 4106 20 Oily Sd 4128 Mud shot 14 0.4 4221 18 Oily Sd 15 1.5 4235 17 Oily Sd 16 1.5 4377 22 Oily Sd 17 1.5 4380 22 Oily Sd 18 1.7 4459 25 Oily Sd 19 1.8 4488 26 Oily Sd 20 1.4 4530 26 Oily Sd 21 1.5 4536 26 Oily Sd 22 1.4 4577 A 26 Oily Sd 23 1.2 4577B 25 Oily Sd 24 1.3 4582 Insufficient Sample 25 1.6 4690 Gray Cly 26 1.6 4732 22 Oily Sd 27 1.6 4737 22 Oily Sd Page 2 ') 180 Azimuth of hand- picked dips 180 Azimith of MSD dips J I'" "', "I'" I f~I:'¡¡>¡~""""'~UiJLl:i/ W.\,!/U.~' ~':(~ Ii' ¡¡¡:~",,'~ \\~·'_1;¡\1Ii¡\1 '~"': ,.,' ' , ¡ Bed BOllßdary{ r~t~!ilfl'll "~~'ÓI'" ","'';''''113·~Ï'Zlf~·4ì''1IZi'!3~'' ¡':'·;"'1b;721 [~~~:,:,i;~'~:~¡~(~~"~;~~':~!I ,I ... "'.,1":: . 'I" ,,1,:1,,' :,,:, ,I! "I '·:i·q·1:r"~ "~'"' ."."""'\'¡.''''''.f ~1r!'" 'I",'I:~ j·~~;'~".,~r:\\·t;': :?!t\:';);¡:~£~~~'~nd;œ:;t:(i:tJ'Q] '~ùr 'IÖ$ÎlniJtblt'1~",J"tfft.f'51I'i1~'41 ,,: "TI'~ .,¡.,,:',.) i!III,~i,~il Statistics of hand- picked dips _1~~~;:::::~;;~;~;1 I~" 'I ti'l ",,." "'.", 1\ :, 'r ~' ~.. " þ\~~~11:;-f'11~":~;:":~r\t' '\~~:~~'r \~ \,~~T1 j.~II(";';' ;11, ~~:J' :'RQY;~.i1I ' ,," ',I,'f~ ~);I:P'H~1,t @,11';30,,', ',,' '" ,I,'" ~':' , . , ,,' li"""< 'I ,,,,,, "'¡ 'hi." ,,,:~,Jr ",~ 0':, ",," '" , ,II III I l 111!1r.!~W'f ì\\\'~¥'~'·')~P'\I'r''I'i)'\..\i''~If,~''r''¡'¡'''''~\'''''~II¡;lj' \N"'ÔflQ*C~'·' 't,4jW,: ,", ./', "1"·" ,'. I , , ~:."il':,.::i:::':":·"i:·¡'}'<:;:,'·',:'!··/",:I~;~,.':>:.',;~;~~~i~~~~:":/:~~'~<;: \'11 I I.' II¡If'A}}\ ff í~ 1¡'\'''¡''''II'''''\~\ 1\1I"II'íl'~f.'f;I"'1 '1'\"'\,'1 ; "'~uf"'P I " 5:.3'$'" ~ í!5¡;'Ø4'" Ž4.91t' I· '" j':"':: I I I '\ ~ ¡.: ! ~ . I' 1 I v..t....r'l't". ~"f i!'h'.~r.'-lllnr- ¡~'1" l....<!Ii", r'~Fr"" '¡~~'\lt'L"\ r'1f."'· It· ,J .' III "¡,,,\/¡1'r \..~I1+V i'ft.t~f"1V\111r '111"1,1 \ I., t""11 ~1 \,I~ ) ~I ('¡rM II "").J~ ~:~itI.'j@\,' .,,. ~;Ð4' :( $Q.1~",'f,O~951 ., ,"'\I,:ï~' I ; ;" 1\' I J ~II~"II" I¡~·. . 4,....""Iph'Ir" ~1,4,o'~"'io'T"I"'''']''''~'' ~.~ ........,.,,~ ,¡~ ""r>l,! , , ,,' , I· ,ÛI'I^" ^, "f'~'''''''' ~ "",·t'jl.." I-¡ f"~\"'''''' ¡,I i~,Oi1;(J·"Um 'r, ' .;21·, I ~ ~"Q41 '(a3~13·", ',¡ .:..',.. ,~, ~ \ \ ',' .,....I..~W.J....,,'~ 1_..~,.r'dl,.",J.r"'\'''.,~ wJ";'¡1'¡·...J lo¡J.~·~~\ Ih,1 :.i ~{~igl~~¡t;~ Statistics of MSD Dips April 21, 1998 Page 0 ') ) ~.. . . I....: L _~.. ,...0-,/ . April 21, 1998 Page 1 11^~~LAB BP Expl. (Alaska), Inc. CL File #: 57111-98103 NWE 2-01 Location: Sec. 19-Tl2N/R11E JViIIJ Prudhoe Bay Field API No.: 50-029- 22866-00 Well Sample Sample Depth API Name Number Rec. Feet Oil Gravity Description Method Co. Date NWE 2-01 1 1.2 3660 13 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 2 1.8 3667 Gray Sd Retort Core Lab 8-Apr-98 NWE 2-01 3 1.5 3694 14 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 4 1.6 3697 Gray Sd Retort Core Lab 8-Apr-98 NWE 2-01 5 1.6 3795 12 OilySd Retort Core Lab 8-Apr-98 .~ NWE 2-01 6 1.0 3805 12 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 7 1.1 3955 14 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 8 1.0 3970 14 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 9 1.5 4004 17 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 10 1.5 4022 Gray Sd Retort Core Lab 8-Apr-98 NWE 2-01 11 1.6 4076 19 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 12 1.6 4085 20 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 13 0.6 4106 20 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 4128 Mud shot Retort Core Lab 8-Apr-98 NWE 2-01 14 0.4 4221 18 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 15 1.5 4235 17 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 16 1.5 4377 22 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 17 1.5 4380 22 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 18 1.7 4459 25 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 19 1.8 4488 26 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 20 1.4 4530 26 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 21 1.5 4536 26 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 22 1.4 4577 A 26 OilySd Retort Core Lab 8-Apr-98 .-" NWE 2-01 23 1.2 4577B 25 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 24 1.3 4582 Insufficient Sample Retort Core Lab 8-Apr-98 NWE 2-01 25 1.6 4690 Gray Cly Retort Core Lab 8-Apr-98 NWE 2-01 26 1.6 4732 22 OilySd Retort Core Lab 8-Apr-98 NWE 2-01 27 1.6 4737 22 OilySd Retort Core Lab 8-Apr-98 Page 1 ·F ROM : POOL8 ) FRX HO.: 6594586 ) 03-28-98 06:35 P.04 NWE2-01 CORE #1 - 6552'TVDss/7034'KD-6583'TVDss/7066'MD - Cut32'/Rec 26.5' - - . . - 7034- - sltst gy bd/v bd calc sm s11 strks NSFOC 7037' - sltst gy hd '51 calc 51 sil ip tr glau fin carb ip NSFOC 7040' - sltst,gy hd sl ca1c tr fin carb œat ip SHOW: no vis stain, fIo, brt mlky yel cut, no vis ring 7043' - sltst gy frm/hd sl calc tr fin earb mat trg1au SHOW:, duli/brt fio, brt mlky yel cut, ace It brn stn, It vis brn "ring 7046' - 55 gy/brn vfL ang/sa y srtd frm/hd 51 calc glau TT(tit, SHOW: dull yel fIc, brt mlky yel cut, m brn stn, ~t/1D brn ring 7049' - ~ brn vfL sr/sa p srtd v slty abnt glau pred n calc TT SHOW; dull yel f10, mod str.g mlky yel cut, m brn stn, v It brn ring 7Q52' - ~ dk brn fL-cU sa/sr p srtd v 51 calc frm abnt g1au p-Ø/TT SHOW: dUll yel flO, brt ml~y yel cut, dk brn s~n, dk brn ring 70551 - sltst dk gy hd 51 calc sil v/lam slts wIlt brn stn SHOW: lam 1t YGl flor O~~ strmg yel CU~, lam It brn s~n no vis ring 70S81 - sltst dk gy hd 51 calc pred ÄA SHOW: lam 1t yel fle, ace strmg yel cut, lam lt brn stn no vis Z'in~ 7060.51-s1tst dk gy hd AA v/incr sIt lams wIlt brn stn SHOW: lam It/dull yel fla, ace strmg yel cut, it brn stn no vis ring ~ -..,..-- -_.._- ~'""..........~u £:Z""I.t"\,. retrieve core, cu~ 3~' f! 7:34, to 7066', fi=¡l FROM: POOLS ) F¡:¡X NO.: 6594586 ") 133-29-98 136:52 P . 15 1I1fE2-01 Core .2 - 6583'TVDss/706&'~-6611ITVDss/7095'~ - CuL 29'/~ec 28.5~ 1066' - s1tst ðk gy v hd v 81 calc ip sil ip occ fin carb mat NSFOC 7069' - s1tst d~ gy AA NSFOC 7072' - SS bra v~U-fL/occ aL sa/sr _ srtd fe./m hd 81 calc ip P-ø SHOW: du11 yel flo, brt strmg .lky yei cut, d~ brn stn d'k brn ring 707~· - s1tst gy v bd sit n calc SHOW:ðull yel £10, .od brt strmg .1ky yel cut, lt brn stn, .. bra ring 7Q78 , - Sltst dk 9Y hd ail pity p~ed n calc v/lam It brn stn SHOW: ace lt dul1 yel flo, mod bet strag mlky yei cut v It brn ring 7Q81' - sltst dk 9Y hd s11 ~A SHOW: oce l~ dul~ yel fI0, .ad brt str.g alky yel cut ~ It brn ring 7084' - sltst dk gy bd si1 pIty pred n ca1c w/~ams l~ brn stn SHOW: ace it dull yel £10, .ad brt strmg mlky yeI cut v it brn ring 7087' - s1tst dk gy bd/frm ail ip AA SHOW: ace v It du11 yet f10, mod brt strmg ml~y yei cut, m brn stD, _ brn ring 709Q' - sltst dk gy fra AA _liner lams It brn stn It dull yel flo, mod brt str.g mlky ye1 cut, It brn stn. It brn ring 7092_4t-sl~st d~ gy bd sil n calc ~/rr It brn stn laas SHOW: rr v It du11 yel fla, tr str.g mlky yel cut, 1t brn stn 1a., no vis ring 7094.5'-sJts~ dk gy bd sil n calc v/rr Ð brn stn la.s SHOW: rr V It du11 yel flo, sm strmg a1ky yel cut, m brn stn la.s, It brn ring Core Description; BPX NW Eileen 2-01 Core #3,9301- 9392' Cut 91', Recovered 91.8' Stratigraphic Interval: lower Kingak Shale- Sag River - upper Shublik-A API: 50-029-22866-00 Prepared by: H. Haywood, 19 April, 1998 Depth 9301 - 9303.4' 9303.4 - 9311.9' 9311.9 - 9325.1' 9325.1 - 9331.1' 9331.1 - 9331.5' 9331.5 - 9338.3' [ lOp Sag R. resevoir) Litholo2V Sbale: dark gy - blk, slightly silty, fissile, hard I silic?, abnt slikensides sub parallel to apparent bedding @ 9301-01.5' Siltstone I Sbale: interbedd, dark-med grey, wI 0.1-0.6 Sh, fissile, hard trace pyritized organic I plant frags, some shale clasts in sltstn, deformed beding. predom Siltstone: med gray, hard I silic, some carbo Frags; wI interlam Shale: dark grey, fissile, some pyrite concretions, Siltstone: dark grey, abnl glauc, carb & part pyritized plant frags, hard I silic, some mud clasts, highly bioturbated, slump deformed bdding. Claystone: light grey, modeerlly soft, some float sand grains Sandstone: It grenish grey, vfL-vtu, sl slty , sub rdd-rdd, qtz overgrwth 30% glauc. decrease to 5% downward, 10-15% pyrite @ top inteval, mod-haevy bioturbation, some clystn parting. Porosity! Cement Shows nil Stn: bleed some dk bm oil on slickensides VC: nil-v. It amber SF: v. pale yell CF: slow V. pale yellow. nil Stn: nil VC: v.lt ambr SF: nil CF: slow V. pale yell. --.-I nil Stn: nil VC: nil SF: nil CF: v. slow pale yell, yell ring nil Stn: nil VC: nil, no vis ring SF: nil-spotty dull yellow CF: slow stnn yellow, grn-yell ring. nil poor I Silic, pyrite Stn: nil VC: nil, no vis ring SF: nil CF: slow-mod stnn pale yell [dry], yell ring. -" NEW 2-01 Core #3 9338.3 - 9356' 9356 - 9362.1 ' 9362.1 - 9373.5' 9373.5 - 9375' [ top Shublik] 9375 - 9382' 9382 - 9389' 9389 - 9390' 9390 - 9392.8' Sandstone: lt grey, vtl.-vfU, well sort, rdd-sub ang, mod quartz overgrowths, pred. Quartz, 1-2% glauc, tr-I % white trip chert grs, traces clay draps, pervasive biturbation, some micro pyrite burrow molds. Large carbonizd wood frag in scour near base interval Sandstone: It grey, vtl.-vfU, w. sort, rdd-sub rdd, abnt xtaI qtz overgrowths, Quartz, 1% wh trip Chert, -I % glauc, v. sl calcareous, bioturbated. Sandstone: It grey-grey, vtL-vfU becoming sl slty near base, rdd-sub ang, quartz over- growths, Quartz wi I % glauc, tr tripolitic Cht grs, mod-heavy silic cmt, calc mt increase near base interval, pervasive bioturbation: Some sub vertical calcite filled fractures. Disconformable-scour base of Sag r. wi reworked underlying shublik fragments. Shale: v. dark grey-blk, slty-v. slty, some float sand grs., carbonaceous, ? phosphate. Limestone: dk brown, microxtalline, tr glauc, abnt bivalves [Monotis?], some 2-5mm calcite filled sub vertical fractures, hard, bioturbated, wavy bdding. Limestone: dark brown, micro-cryptoxtal, abundant bivalves [ Monotis?] bioturbated. Siltstone: dk brown, grades to Sandstone, Uslt-vtL, Quartz, tr glauc, v. calcareous, some bioturbation. Limestone: brown, microxtalline, some flat qtz grs, some interlam & float Clystone, minor glauconite, abnt bivalves, tr carbonaceous frags, re-worked - bioturbated p.2 poor - fair / mod. Silic Stn: tr It bm-patchy dk bm VC: v.lt amber, intennittent v.lt bm ring SF: mottled-even dull yell - brt yell CF: flash-strm pale-mlky yell, yell ring. fair / Silic Stn: It bm, bleed trs dk bm oil VC: nil -It amber SF: even yell - dull yell CF: flash-stnn sl mlky yell, brt yell ring. fair-poor I Silic, CaCO] Stn: nil- patchy It bm, tr dk bm VC: nil-v. It amber SF: nil, rare v. dull yellow CF: slow-strm pale yellow,yell-omg yell ring. '"-"~ Nil Sin: trace black Nil Sin: It-dk bm VC: nil-tr v.lt amber SF: nil CF: v. slow v. pale yell, pale yell ring Nil Stn: It-dk bm VC: nil SF: nil CF: nil- v. slow v. pale yellow Nill Silic, CaC03 Nil v. poor-nill Calc Sin: weak It-med bm VC: nil SF: nil CF: v. slow pale yell, v. pale yell ring .----~ Performance Enquiry Report Operator BP Exploration Date 21:30,06 May 98 Formation Integrity Test for NWE 2-01 The analysis is from - 08:30, 18 Mar 98 - to - 08:30, 15 Apr 98 Programs in Result Table: NWE 02-01 well NWE 02-01 NWE 02-01 Type Event Event Time From Time To Duration Description o hr 0 min Obtained leak off o hr 0 min Obtained leak off Depth MDR 3780.0 9300.0 E.M.W. (equivalent mud weight) 12.5 15.9 08:30. 18 Mar 98 08:30. 15 Apr 98 08:30, 18 Mar 98 08:30, 15 Apr 98 Page Hole Size MDR 12-1/4 8-1/2 1 .~ .~. Facility EX NWE#2 DatelTime 04 Mar 98 06:00-06:30 06:30-12:00 12:00-18:00 18:00-18:30 18:30-00:00 05 Mar 98 00:00-06:00 06:00-06:00 06 Mar 98 06:00-06:00 07 Mar 98 06:00-06:00 08 Mar 98 06:00-14:00 14:00-15:30 15:30-06:00 09 Mar 98 06:00-18:00 18:00-19:00 19:00-06:00 10 Mar 98 06:00-11:00 11:00-14:00 14:00-18:00 18:00-19:00 19:00-20:00 20:00-01:30 11 Mar 98 01:30-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-12:00 12:00-18:00 18:00-19:00 19:00-02:00 12 Mar 98 02:00-02:30 02:30-06:00 06:00-11:30 11:30-12:00 12:00-13:30 13:30-14:30 14:30-20:00 20:00-21:00 21 :00-06:00 13 Mar 98 06:00-11:00 11:00-13:00 13:00-15:00 15:00-17:00 17:00-19:00 19:00-21:00 21 :00-00:00 14 Mar 98 00:00-01:00 01:00-01:30 01 :30-06:00 06:00-08:00 08:00-10:00 10:00-12:00 12:00-14:00 14:00-14:30 14:30-15:30 Duration 1/2 hr 5-1/2 hr 6 hr 1/2 hr 5-1/2 hr 6 hr 24 hr 24 hr 24 hr 8 hr 1-1/2 hr 14-1/2 hr 12 hr 1 hr 11hr 5 hr 3 hr 4 hr 1 hr 1 hr 5-1/2 hr 3-1/2 hr 1 hr 1/2 hr 1-1/2 hr 4hr 6 hr 1 hr 7 hr 1/2 hr 3-1/2 hr 5-1/2 hr 1/2 hr 1-1/2 hr 1 hr 5-1/2 hr 1 hr 9 hr 5 hr 2 hr 2hr 2hr 2 hr 2hr 3hr 1 hr 1/2 hr 4-1/2 hr 2 hr 2 hr 2 hr 2 hr 1/2 hr 1 hr ) ) Progress Report Well NWE 02-01 Rig POOL 8 Page 1 Date 06 May 98 Activity Held safety meeting Rigged up High pressure lines Rigged up High pressure lines Held safety meeting Rigged up Surface lines Rigged up Divertor Rigged up Divertor (cont...) Rigged up Draw works Rigged up Draw works Rigged up Draw works (cont...) Tested Divertor Rigged up Draw works Rigged up Draw works (cont...) Held safety meeting Rigged up Drillstring handling equipment Rigged up Drillstring handling equipment (cont...) Made up BHA no. 1 Serviced Drillstring handling equipment Circulated at 103.0 ft Drilled to 143.0 ft Repaired Washpipe Drilled to 324.0 ft Laid down 220.0 ft of 5in OD drill pipe Laid down 220.0 ft of 5in OD drill pipe Repaired Washpipe Made up BHA no. 1 Drilled to 600.0 ft Repaired SCR Drilled to 998.0 ft Repaired SCR Drilled to 1234.0 ft Drilled to 1234.0 ft (cont...) Circulated at 1493.0 ft Pulled out of hole to 712.0 ft R.I.H. to 1493.0 ft Drilled to 1864.0 ft Circulated at 1864.0 ft Drilled to 2525.0 ft Drilled to 2680.0 ft (cont...) Circulated at 2680.0 ft Pulled out of hole to 712.0 ft R.I.H. to 2680.0 ft Circulated at 2680.0 ft Pulled out of hole to 712.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 13-3/8in (2000.0 ft OD) Ran Casing to 2664.0 ft (13-3/8in OD) (cont...) Rigged down Casing handling equipment Ran Drillpipe to 2576.0 ft (Sin OD) Circulated at 2664.0 ft Pumped Water based mud spacers - volume 100.000 bbl Mixed and pumped slurry - 480.000 bbl ',' ) ) Progress Report Facility EX NWE#2 Well NWE 02-01 Page 2 Rig POOL 8 Date 06 May 98 DatelTime Duration Activity 15:30-16:00 1/2 hr Mixed and pumped slurry - 97.000 bbl 16:00-16:30 1/2 hr Displaced slurry - 46.000 bbl 16:30-18:00 1-1/2 hr Pulled Drillpipe in stands to 0.0 ft 18:00-19:00 1 hr Cleared Trip tank 19:00-21:00 2 hr Bleed down well 21 :00-05:00 8 hr Rigged down Divertor 15 Mar 98 05:00-06:00 1 hr Installed Casing head 06:00-10:00 4hr Installed Casing head (cont...) 10:00-11:00 1 hr Tested Casing head 11 :00-15:00 4 hr Removed Casing head 15:00-19:00 4 hr Installed Casing head 19:00-06:00 11hr Serviced Casing head 16 Mar 98 06:00-12:00 6 hr Serviced Casing head (cont...) 12:00-01:30 13-1/2 hr Rigged up All functions 17 Mar 98 01 :30-06:00 4-1/2 hr Tested All functions 06:00-10:00 4 hr Tested All functions (cont...) 10:00-11 :00 1 hr Serviced Bell nipple 11 :00-15:00 4 hr Made up BHA no. 2 15:00-15:30 1/2 hr R.I.H. to 1467.0 ft 15:30-18:00 2-1/2 hr Laid down 744.0 ft of 5in aD drill pipe 18 :00-19:00 1 hr R.I.H. to 2578.0 ft 19:00-21:00 2 hr Circulated at 2578.0 ft 21:00-21:30 1/2 hr Held safety meeting 21 :30-23:30 2hr Tested Casing - Via string 23:30-00:00 1/2 hr Held drill (Kick (well kill)) 18 Mar 98 00:00-03:15 3-1/4 hr Drilled installed equipment - Float shoe 03: 15-03:30 1/4 hr Drilled to 2690.0 ft 03:30-05:00 1-1/2 hr Circulated at 2690.0 ft 05:00-05:30 1/2 hr Drilled to 2700.0 ft 05:30-06:00 1/2 hr Circulated at 2700.0 ft 06:00-07:00 1 hr Circulated at 2700.0 ft (cont...) 07:00-08:30 1-1/2 hr Performed formation integrity test 08:30-23:00 14-1/2 hr Drilled to 3689.0 ft 23 :00-00:00 1 hr Circulated at 3689.0 ft 19 Mar 98 00:00-01:00 1 hr Circulated at 3689.0 ft 01:00-02:00 1 hr Pulled out of hole to 2665.0 ft 02:00-02:30 1/2 hr Repaired Additional services 02:30-03:00 1/2 hr Serviced Brake 03:00-03:30 1/2 hr R.I.H. to 3648.0 ft 03:30-04:00 1/2 hr Washed to 3689.0 ft 04:00-06:00 2 hr Drilled to 3780.0 ft 06:00-12:30 6-1/2 hr Drilled to 4122.0 ft (cont...) 12:30-13:00 1/2 hr Circulated at 4122.0 ft 13:00-23:00 10 hr Drilled to 4462.0 ft 23:00-00:00 1 hr Repaired Mud pumps 20 Mar 98 00:00-06:00 6 hr Drilled to 4678.0 ft 06:00-07:30 1-1/2 hr Drilled to 4741.0 ft 07:30-09:00 1-1/2 hr Repaired Liner 09:00-19:00 10 hr Drilled to 5144.0 ft 19:00-19:30 1/2 hr Repaired Fluid system 19:30-20:00 1/2 hr Drilled to 5175.0 ft 20:00-21:00 Ihr Circulated at 5175.0 ft 21:00-22:00 1 hr Pulled out of hole to 3649.0 ft 22:00-22:30 1/2 hr R.I.H. to 5175.0 ft ) ) Progress Report Facility EX NWE#2 Well NWE 02-01 Page 3 Rig POOL 8 Date 06 May 98 DatelTime Duration Activity 22:30-06:00 7-1/2 hr Drilled to 5361.0 ft 21 Mar 98 06:00-22:00 16 hr Drilled to 5938.0 ft 22:00-00:00 2hr Circulated at 5938.0 ft 22 Mar 98 00:00-03:30 3-1/2 hr Pulled out of hole to 147.0 ft 03:30-05:00 1-1/2 hr Pulled BRA 05:00-06:00 1 hr Made up BRA no. 3 06:00-07:30 1-1/2 hr Made up BRA no. 3 (cont...) 07:30-10:30 3 hr R.I.R. to 2629.0 ft 10: 30-12:00 1-1/2 hr Serviced Block line 12:00-13:00 1 hr Repaired Draw works 13:00-14:00 1 hr Functioned downhole tools at 2629.0 ft 14:00-17:30 3-1/2 hr RI.R. to 5878.0 ft 17:30-18:00 1/2 hr Washed to 5948.0 ft 18:00-06:00 12 hr Drilled to 6240.0 ft 23 Mar 98 06:00-06:00 24 hr Drilled to 6848.0 ft (cont...) 24 Mar 98 06:00-06:00 Ohr Circulated at 6847.0 ft 06:00-08:30 2-1/2 hr Circulated at 6847.0 ft 08:30-14:00 5-1/2 hr Pulled out of hole to 230.0 ft 14:00-16:30 2-1/2 hr Pulled BRA 16:30-17:30 1 hr Serviced Wear bushing 17:30-19:30 2 hr Made up BRA no. 4 19:30-22:00 2-1/2 hr RI.R. to 2545.0 ft 22:00-06:00 8 hr Tested BOP stack 25 Mar 98 06:00-07:00 1 hr Tested BOP stack (cont...) 07:00-07:30 1/2 hr Retrieved Wear bushing 07:30-08:30 1 hr Pulled out of hole to 2450.0 ft 08:30-09:00 1/2 hr RI.R. to 2600.0 ft 09:00-10:00 1 hr Circulated at 2665.0 ft 10:00-11 :00 1 hr RI.R. to 3900.0 ft 11:00-12:00 1 hr Circulated at 3900.0 ft 12:00-13:30 1-1/2 hr RI.R. to 5230.0 ft 13:30-15:00 1-1/2 hr Circulated at 5230.0 ft 15:00-15:30 1/2 hr RI.R. to 5240.0 ft 15:30-16:00 1/2 hr Washed to 5333.0 ft 16:00-16:30 1/2 hr Pulled out of hole to 5116.0 ft 16:30-17:30 1 hr R.I.R. to 6758.0 ft 17:30-18:00 1/2 hr Washed to 6848.0 ft 18:00-19:30 1-1/2 hr Circulated at 6848.0 ft 19:30-06:00 10-1/2 hr Drilled to 7019.0 ft 26 Mar 98 06:00-07:00 1 hr Drilled to 7034.0 ft 07:00-13:30 6-1/2 hr Circulated at 7034.0 ft 13:30-14:00 1/2 hr Circulated at 7034.0 ft 14:00-18:00 4hr Pulled out of hole to 7034.0 ft 18:00-19:00 Ihr Pulled BRA 19:00-22:00 3 hr Made up BRA no. 5 22:00-02:30 4-112 hr RI.R. to 7034.0 ft Cò"........ 27 Mar 98 02:30-05:00 2-1/2 hr Circulated at 7034.~- . 05:00-06:00 Ihr Cored to 7035.0 ft ~.. 06:00-11 :00 5hr Cored to 7035.0 ft 11:00-12:00 Ihr Circulated at 7066.0 ft 12:00-18:00 6 hr Pulled out of hole to 7066.0 ft 18:00-19:00 Ihr Pulled BRA 19:00-20:00 Ihr Made up BRA no. 6 20:00-00:00 4hr RI.R. to 6961.0 ft Facility EX NWE#2 DatelTime 28 Mar 98 00:00-02:00 02:00-03:00 03:00-06:00 06:00-09:00 09:00-10:00 10:00-16:00 16:00-18:00 18:00-20:30 20:30-01:00 29 Mar 98 01:00-01:30 01 :30-06:00 06:00-22:00 22:00-03:30 30 Mar 98 03:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-09:30 09:30-10:00 10:00-14:30 14:30-18:30 18:30-19:00 19:00-23:00 23 :00-02:00 31 Mar 98 02:00-04:30 04:30-06:00 06:00-11:30 11 :30-12:00 12:00-12:30 12:30-14:30 14:30-17:30 17:30-18:00 18:00-18:30 18:30-00:00 01 Apr 98 00:00-01:30 01:30-02:00 02:00-03:00 03:00-06:00 06:00-07:30 07:30-19:30 19:30-20:30 20:30-22:30 22:30-00:00 02 Apr 98 00:00-00:30 00:30-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-07:00 07:00-10:30 10:30-11 :00 11:00-13:30 13 :30-14:00 14:00-19:00 Duration 2 hr 1 hr 3 hr 3 hr 1 hr 6 hr 2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 4-1/2 hr 16 hr 5-1/2 hr 2-1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1/2 hr 4-1/2 hr 4 hr 1/2 hr 4 hr 3 hr 2-1/2 hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 2 hr 3 hr 1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 12 hr 1 hr 2hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 5 hr ) ) Progress Report Well NWE 02-01 Rig POOL 8 Page 4 Date 06 May 98 Activity Reamed to 7066.0 ft Circulated at 7066.0 ft Cored to 7090.0 ft Cored to 7095.0 ft Circulated at 7095.0 ft Pulled out of hole to 7095.0 ft Pulled BHA Made up BHA no. 7 R.I.H. to 7003.0 ft Reamed to 7033.0 ft Drilled to 7084.0 ft Drilled to 7476.0 ft (cont...) Circulated at 7476.0 ft Pulled out of hole to 4000.0 ft Pulled out of hole to 847.0 ft (cont...) Pulled BHA Downloaded MWD tool Pulled BHA Held safety meeting Conducted electric cable operations Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Installed Formation logs Ran logs on tubulars Ran logs on tubulars (cont...) Circulated at 5021.0 ft Held safety meeting Conducted electric cable operations Ran logs on tubulars Pulled out of hole to 5021.0 ft Conducted electric cable operations Pulled out of hole to 82.0 ft Rigged down sub-surface equipment - Formation logs Held safety meeting Made up BHA no. 8 RI.H. to 2665.0 ft RI.H. to 5237.0 ft (cont...) Reamed to 6143.0 ft Circulated at 6143.0 ft Reamed to 6253.0 ft RI.H. to 7218.0 ft Held safety meeting Washed to 7476.0 ft Circulated at 7476.0 ft Pulled out of hole to 4443.0 ft Pulled out of hole to 2600.0 ft (cont...) Held drill (Kick while tripping) R.I.H. to 7415.0 ft Washed to 7476.0 ft Circulated at 7476.0 ft Circulated at 7476.0 ft Pulled out of hole to 815.0 ft ) ) Progress Report Facility EX NWE#2 Well NWE 02-01 Page 5 Rig POOL 8 Date 06 May 98 Dateffime Duration Activity 19:00-20:30 1-1/2 hr Pulled BHA 20:30-21:00 1/2 hr Held safety meeting 21 :00-06:00 9hr Conducted electric cable operations 03 Apr 98 06:00-06:30 1/2 hr Conducted electric cable operations 06:30-11:00 4-1/2 hr Conducted electric cable operations 11:00-19:30 8-1/2 hr Conducted electric cable operations 19:30-00:00 4-1/2 hr Tested BOP stack 04 Apr 98 00:00-03:00 3 hr Made up BHA no. 9 03:00-04:30 1-1/2 hr RI.H. to 2640.0 ft 04:30-04:45 1/4 hr Held drill (Kick while tripping) 04:45-06:00 1-1/4hr Serviced Block line 06:00-06: 15 1/4 hr Serviced Block line (cont...) 06: 15-06:30 1/4 hr Serviced Draw works 06:30-07:30 1 hr Tested MWDIL WD - Via string 07:30-08:00 1/2 hr Held drill (H2S) 08:00-10:00 2hr R.I.H. to 5267.0 ft 10:00-12:00 2 hr RI.H. to 7476.0 ft 12:00-12:30 1/2 hr Circulated at 7476.0 ft 12:30-15:00 2-1/2 hr Drilled to 7490.0 ft 15:00-17:00 2 hr Circulated at 7490.0 ft 17:00-18:00 1 hr Circulated at 7490.0 ft 18:00-20:00 2 hr Pulled out of hole to 4690.0 ft 20:00-20:30 1/2 hr Flow check 20:30-22:00 1-1/2 hr R.I.H. to 7490.0 ft 22:00-23:30 1-1/2 hr Circulated at 7490.0 ft 23:30-04:30 5 hr Pulled out of hole to 848.0 ft 05 Apr 98 04:30-06:00 1-1/2 hr Pulled BHA 06:00-06:30 1/2 hr Pulled BHA 06:30-09:30 3 hr Made up BHA no. 10 09:30-11:00 1-1/2 hr R.I.H. to 2650.0 ft 11 :00-14:00 3 hr Repaired Draw works 14:00-16:00 2 hr RI.H. to 5267.0 ft 16:00-18:00 2 hr R.I.H. to 7490.0 ft 18:00-19:00 1 hr Repaired SCR 19:00-06:00 11hr Drilled to 7729.0 ft 06 Apr 98 06:00-05:00 23 hr Drilled to 8375.0 ft (cont...) 07 Apr 98 05:00-06:00 1 hr Repaired SCR 06:00-13:30 7-1/2 hr Repaired SCR 13:30-17:30 4 hr Pulled out of hole to 2500.0 ft 17:30-20:30 3 hr Repaired Draw works 20:30-22:00 1-1/2 hr Pulled out of hole to 880.0 ft 22:00-00:00 2hr Pulled BHA 08 Apr 98 00:00-02:00 2hr Made up BHA no. 11 02:00-06:00 4 hr R.I.H. to 7000.0 ft 06:00-07:00 1 hr RI.H. to 7464.0 ft (cont...) 07:00-08:00 1 hr Washed to 8375.0 ft 08:00-02:45 18-3/4 hr Drilled to 8716.0 ft 09 Apr 98 02:45-04:15 1-1/2 hr Serviced Pistons 04: 15-06:00 1-3/4 hr Drilled to 8800.0 ft 06:00-06:30 1/2 hr Serviced Mud pumps 06:30-08:30 2 hr Drilled to 8832.0 ft 08:30-09:30 Ihr Serviced Mud pumps 09:30-13:30 4hr Drilled to 8860.0 ft 13:30-20:00 6-1/2 hr Pulled out of hole to 210.0 ft Facility EX NWE#2 DatelTime 20:00-21:00 21:00-00:00 10 Apr 98 00:00-05:00 05 :00-06:00 06:00-08:00 08:00-10:00 10:00-11:00 11:00-11:30 11:30-13:00 13:00-15:30 15:30-06:00 11 Apr 98 06:00-09:00 09:00-10:30 10:30-13:00 13:00-15:30 15:30-17:00 17:00-17:30 17:30-22:30 22:30-01:30 12 Apr 98 01 :30-02:00 02:00-02:30 02:30-05:30 05:30-06:00 06:00-11:30 11:30-13:00 13:00-16:00 16:00-18:00 18:00-19:00 19:00-19:30 19:30-00:00 13 Apr 98 00:00-01:00 01:00-06:00 06:00-09:00 09:00-11:00 11:00-12:00 12:00-13:30 13:30-18:30 18:30-19:00 19:00-19:30 19:30-20:00 20:00-21 :00 21:00-22:15 22: 15-22:30 22:30-23:30 23:30-00:00 14 Apr 98 00:00-01:00 01 :00-02:30 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07 :00-12:00 12:00-14:00 Duration 1 hr 3 hr 5 hr 1 hr 2 hr 2hr 1 hr 1/2 hr 1-1/2 hr 2-1/2 hr 14-1/2 hr 3 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 5 hr 3 hr 1/2 hr 1/2 hr 3 hr 1/2 hr 5-1/2 hr 1-1/2 hr 3 hr 2 hr 1 hr 1/2 hr 4-1/2 hr 1 hr 5 hr 3 hr 2 hr 1 hr 1-1/2 hr 5 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 1-1/4 hr 1/4 hr 1 hr 1/2 hr 1 hr 1-ll2hr 1 hr 1/2 hr 1hr 1 hr Ihr 5 hr 2 hr ) -) Progress Report Well NWE 02-01 Rig POOL 8 Page 6 Date 06 May 98 Activity Pulled BHA Made up BHA no. 12 Tested BOP stack R.I.H. to 200.0 ft R.I.H. to 2665.0 ft (cont...) Serviced Block line R.I.H. to 5270.0 ft Took MWD survey at 5270.0 ft R.I.H. to 8860.0 ft Washed to 8868.0 ft Drilled to 9125.0 ft Drilled to 9218.0 ft (cont...) Repaired Pistons Drilled to 9280.0 ft Circulated at 9280.0 ft Pulled out of hole to 7380.0 ft R.I.H. to 8880.0 ft Reamed to 8889.0 ft Circulated at 9280.0 ft Pulled out of hole to 8335.0 ft R.I.H. to 9280.0 ft Circulated at 9280.0 ft Pulled out of hole to 8500.0 ft Pulled out of hole to 200.0 ft (cont...) Pulled BHA Tested Top ram Space out tubulars Rigged up Casing handling equipment Held safety meeting Ran Casing to 2664.0 ft (9-5/8in OD) Circulated at 2664.0 ft Ran Casing to 9-5/8in (6000.0 ft OD) Ran Casing to 9243.0 ft (9-5/8in OD) (cont...) Washed to 9273.0 ft Circulated at 9273.0 ft Repaired High pressure lines Repaired High pressure lines Tested High pressure lines Held safety meeting Pumped Water spacers - volume 90.000 bbl Mixed and pumped slurry - 89.600 bbl Displaced slurry - 701.000 bbl Functioned DV collar Circulated at 7414.0 ft Pumped Water spacers - volume 70.000 bbl Mixed and pumped slurry - 532.000 bbl Displaced slurry - 561.000 bbl Rigged down Casing handling equipment Installed Seal assembly Tested Seal assembly Injectivity test - 30.000 bbl injected at 1475.0 psi Freeze protect well - 120.000 bbl of Diesel Tested BOP stack Made up BHA no. 13 Facility EX NWE#2 DatelTime 14:00-16:30 16:30-17:00 17:00-19:30 19:30-22:00 22:00-23:00 23:00-00:00 15 Apr 98 00:00-03:00 03:00-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-12:00 12:00-20:00 20:00-20:30 20:30-01:00 16 Apr 98 01:00-02:00 02:00-03:00 03:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-12:00 12:00-12:30 12:30-13:00 13:00-15:30 15:30-20:00 20:00-20:30 20:30-22:00 22:00-05:00 17 Apr 98 05:00-06:00 06:00-06:30 06:30-08:00 08:00-10:30 10:30-11:00 11:00-13:30 13:30-16:00 16:00-18:00 18:00-20:30 20:30-06:00 18 Apr 98 06:00-20:00 20:00-20:30 20:30-21:30 21 :30-22:00 22:00-00:00 19 Apr 98 00:00-04:00 04:00-06:00 06:00-07:00 07:00-08:30 08:30-09:00 09:00-13:00 13:00-15:00 Duration 2-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 1 hr 1 hr 3 hr 1/2 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 8 hr 1/2 hr 4-1/2 hr 1 hr 1 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 7 hr 1 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 2hr 2-1/2 hr 9-1/2 hr 14 hr 1/2 hr 1 hr 1/2 hr 2hr 4 hr 2 hr 1 hr 1-1/2 hr 1/2 hr 4 hr 2 hr ) ) Progress Report Well NWE 02-01 Rig POOL 8 Page 7 Date 06 May 98 Activity RI.H. to 7364.0 ft Washed to 7416.0 ft Drilled installed equipment - DV collar RI.H. to 9186.0 ft Circulated at 9186.0 ft Tested Casing Drilled installed equipment - Landing collar Drilled installed equipment - Float collar Drilled installed equipment - Float shoe Drilled cement to 9280.0 ft Drilled to 9292.0 ft Drilled to 9300.0 ft (conL.) Circulated at 9300.0 ft Performed formation integrity test Circulated at 9300.0 ft Cleared Mud shakers Circulated at 9300.0 ft Pulled out of hole to 125.0 ft Pulled BHA Repaired Casing handling equipment Made up BHA no. 14 R.I.H. to 292.0 ft Made up BHA no. 14 Made up BHA no. 14 R.I.H. to 9268.0 ft Circulated at 9300.0 ft Repaired Suction valve Circulated at 9300.0 ft Cored to 9391.0 ft Laid down 115.0 ft of 5in OD drill pipe Circulated at 9391.0 ft Pulled out of hole to 112.0 ft Laid out Aluminium sleeve core Laid out Aluminium sleeve core Made up BHA no. 15 Serviced Block line Downloaded MWD tool Made up BHA no. 15 R.I.H. to 4284.0 ft R.I.H. to 9268.0 ft Logged hole with LWD: Formation evaluation (FE) from 9220.0 ft to 9391.0 ft Drilled to 9500.0 ft Drilled to 9815.0 ft Circulated at 9815.0 ft Pulled out of hole to 9268.0 ft RI.H. to 9815.0 ft Circulated at 9815.0 ft Pulled out of hole to 759.0 ft Pulled BHA Pulled BHA Rigged up sub-surface equipment - Formation logs Held safety meeting Ran Drillpipe to 9264.0 ft (5in OD) Rigged up Logginglbraided cable equipment iii Facility EX NWE#2 Datetrime 15:00-06:00 20 Apr 98 06:00-07:00 07:00-08:00 08:00-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-17:00 17:00-21:00 21:00-21:30 21 :30-23:00 23 :00-00:00 21 Apr 98 00:00-00:30 00:30-01:00 01:00-01:30 01 :30-03:00 03:00-06:00 06:00-07:00 07:00-09:30 09:30-11:30 11 :30-12:00 12:00-20:00 20:00-21:30 21:30-22:30 22:30-23:00 23:00-01:30 22 Apr 98 06:00-12:00 12:00-14:30 14:30-18:00 18:00-06:00 23 Apr 98 06:00-18:00 18:00-00:00 24 Apr 98 00:00-06:00 06:00-12:00 12:00-18:00 18:00-00:00 25 Apr 98 00:00-06:00 Duration 15 hr 1 hr 1 hr 4 hr 1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 4 hr 1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 3 hr 1 hr 2-1/2 hr 2 hr 1/2 hr 8 hr 1-1/2 hr 1 hr 1/2 hr 2-1/2 hr 6 hr 2-1/2 hr 3-1/2 hr 12 hr 12 hr 6 hr 6 hr 6hr 6 hr 6 hr 6 hr ) ) Progress Report Well NWE 02-01 Rig POOL 8 Page 8 Date 06 May 98 Activity Conducted electric cable operations Pulled Drillpipe in stands to 9264.0 ft Rigged down Rigging equipment Pulled out of hole to 800.0 ft Pulled out of hole to 0.0 ft Rigged down Logginglbraided cable equipment Rigged up Tubing handling equipment Ran Tubing to 2091.0 ft (3-1/2in OD) Ran Drillpipe to 9250.0 ft (5in OD) Ran Drillpipe to 9816.0 ft (5in OD) Circulated at 9816.0 ft Rigged up Cement head Mixed and pumped slurry - 64.000 bbl Pulled Drillpipe in stands to 8875.0 ft Circulated at 8875.0 ft Circulated at 8875.0 ft Laid down 2511.0 ft of 5in OD drill pipe Laid down 372.0 ft of Drillpipe Singled in drill pipe to 9005.0 ft Rigged down Kelly Circulated at 9005.0 ft Laid down 6914.0 ft of 5in OD drill pipe Installed Tubing hanger Circulated at 2091.0 ft Installed Emergency seal assembly Rigged down Kelly Rigged down BOP stack Installed Xmas tree Cleared Mud pumps Rig moved 20.00 % Rig moved 40.00 % (cont...) Rig moved 60.00 % Rig moved 60.00 % Rig moved 80.00 % Rig moved 85.00 % Rig moved 85.00 % Rig moved 90.00 % ) AK Exploration Alaska State Plane Zone 4 NWE NWE 02-01 ORIGINAl SURVEY REPORT 2 June, 1998 " l Your Ref: API-500292286600 Last Survey 18-Aprff-98 Job# AKMM80137 KBE - 74.06' Surface Coordinates: 5986606.00 N, 570682.00 E (70022' 25.4193" N, 210034' 28.2532" E) spe............v-sun DRILLING seRVices A DIVWON or DU3SER INDUn.o:s. C"c. q~ . ()~5 Co IO'::/~ 6 &117/ RECEIVED JUN 0 3 1998 BPXA PDC CO\F~'JE\"'A- Survey Ref: svy72 Sperry-Sun Drilling Services . Survey Report for NWE 02-01 Your Ref: API-500292286600 Alaska State Plane Zone 4 AK Exploration NWE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg VerticaJ Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) (ft) ') 0.00 0.000 0.000 -74.06 0.00 O.OON 0.00 E 5986606.00 N 570682.00 E 0.00 136.12 0.020 225.330 62.06 136.12 0.028 0.02W 5986605.98 N 570681.98 E 0.015 ' -0.02 243.02 0.050 250.370 168.96 243.02 0.058 0.07W 5986605.95 N 570681.93 E 0.031 -0.07 339.45 0.320 93.690 265.39 339.45 0.088 0.15 E 5986605.92 N 570682.16 E 0.380 0.00 427.01 0.230 82.130 352.95 427.01- 0.078 0.57 E 5986605.94 N 570682.57 E 0.120 0.21 520.34 0.110 99.040 446.28 520.34 0.06S 0.85 E 5986605.95 N 570682.85 E 0.138 0.35 606.87 0.580 244.640 532.81 606.87 0.268 0.53 E 5986605.75 N 570682.54 E 0.778 0.02 696.81 0.620 240.380 622.74 696.80 0.698 0.30W 5986605.30 N 570681.71 E 0.067 -0.75 788.88 0.530 242.240 714.81 788.87 1.148 1.11 W 5986604.85 N 570680.90 E 0.100 -1.53 881.39 0.370 211.860 807.31 881.37 1.598 1.65W 5986604.39 N 570680.37 E 0.305 -2.18 973.71 0.400 220.780 899.63 973.69 2.098 2.01 W 5986603.89 N 570680.00 E 0.072 -2.79 1065.82 0.380 231.860 991.74 1065.80 2.528 2.47W 5986603.46 N 570679.56 E 0.085 -3.38 1162.57 0.250 228.160 1088.49 1162.55 2.868 2.87W 5986603.11 N 570679.15 E 0.136 -3.87 1258.37 0.320 229.850 1184.29 1258.35 3.178 3.23W 5986602.80 N 570678.80 E 0.074 -4.32 1349.32 0.350 219.350 1275.24 1349.30 3.558 3.61 W 5986602.42 N 570678.43 E 0.075 -4.83 1439.36 0.320 273.110 1365.27 1439.33 3.75S 4.03W 5986602.21 N 570678.00 E 0.338 -5.20 1535.17 0.200 249.990 1461.08 1535.14 3.798 4.45 W 5986602.17 N 570677.58 E 0.164 -5.44 1627.74 0.350 271.360 1553.65 1627.71 3.848 4.89W 5986602.11 N 570677.15 E 0.194 -5.69 ) 1720.35 0.320 205.370 1646.26 1720.32 4.078 5.28W 5986601.88 N 570676.76 E 0.395 -6.07 1809.03 0.360 261.200 1734.94 1809.00 4.338 5.66W 5986601.61 N 570676.38 E 0.361 -6.48 1994.11 0.620 296.690 1920.01 1994.07 3.97 S 7.13W 5986601.96 N 570674.90 E 0.210 -6.86 2087.38 0.540 286.470 2013.28 2087.34 3.628 8.01 W 5986602.30 N 570674.03 E 0.140 -6.95 2180.43 0.380 273.740 2106.33 2180.39 3.48 8 8.73W 5986602.44 N 570673.30 E 0.203 -7.17 2273.84 0.320 289.740 2199.73 2273.79 3.378 9.29 W 5986602.54 N 570672.74 E 0.122 -7.33 2366.51 0.330 299.980 2292.40 2366.46 3.158 9.76W 5986602.76 N 570672.27 E 0.064 -7.36 2459.40 0.230 311.960 2385.29 2459.35 2.898 10.13 W 5986603.02 N 570671.89 E 0.124 -7.31 2556.61 0.260 317.450 2482.50 2556.56 2.608 10.43 W 5986603.31 N 570671.60 E 0.039 -7.19 2632.02 0.260 333.650 2557.91 2631.97 2.32 S 10.62 W 5986603.58 N 570671.40 E 0.097 -7.03 2697.65 0.220 347.250 2623.54 2697.60 2.068 10.71 W 5986603.84 N 570671.31 E 0.106 -6.85 2790.17 1.380 41.670 2716.05 2790.11 1.058 10.01 W 5986604.85 N 570672.00 E 1.367 -5.63 Continued... 2 June, 1998 - 11:38 -2- DrillQuest Sperry-Sun Drilling Services . Survey Report for NWE 02-01 Your Ref: API-500292286600 Alaska State Plane Zone 4 AK Exploration NWE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) (ft) 2882.37 3.490 37.470 2808.16 2882.22 2.00 N 7.57W 5986607.93 N 570674.41 E 2.295 -1.78 ) 2971.89 5.250 21.360 2897.42 2971.48 7.98 N 4.42W 5986613.94 N 570677.51 E 2.379 4.97 3067.09 8.730 14.250 2991.90 3065.96 19.04 N 1.05W 5986625.03 N 570680.77 E 3.760 16.32 3160.06 9.330 14.560 3083.72 3157.78 33.17 N 2.58 E 5986639.20 N 570684.27 E 0.647 30.50 3251.87 10.130 14.580 3174.21 3248.27 48.19 N 6.48 E 5986654.25 N 570688.03 E 0.871 45.60 3344.20 11.450 15.990 3264.90 3338.96 64.86 N 11.05 E 5986670.96 N 570692.44 E 1.458 62.46 3437.12 12.890 16.400 3355.73 3429.79 83.67 N 16.52 E 5986689.82 N 570697.73 E 1.552 81.64 3528.32 14.660 7.070 3444.32 3518.38 104.89 N 20.81 E 5986711.08 N 570701.82 E 3.109 102.38 3619.66 16.140' 6.140 3532.37 3606.43 128.98 N 23.59 E 5986735.20 N 570704.37 E 1.643 124.97 3716.00 18.430 7.120 3624.36 3698.42 157.41 N 26.91 E 5986763.66 N 570707.43 E 2.396 151.63 3809.47 20.450 10.110 3712.50 3786.56 188.15 N 31.61 E 5986794.44 N 570711.83 E 2.408 180.98 3902.00 22.840 13.240 3798.50 3872.56 221.55 N 38.56 E 5986827.90 N 570718.47 E 2.868 213.73 3994.17 26.030 12.550 3882.40 3956.46 258.71 N 47.06 E 5986865.15 N 570726.61 E 3.475 250.54 4087.46 30.870 12.630 3964.40 4038.46 302.07 N 56.74 E 5986908.60 N 570735.89 E 5.188 293.37 4179.10 32.780 13.150 4042.26 4116.32 349.18 N 67.53 E 5986955.80 N 570746.23 E 2.106 340.03 4264.73 32.760 13.270 4114.26 4188.32 394.30 N 78.12 E 5987001.02 N 570756.39 E 0.079 384.84 4367.89 34.230 8.240 4200.31 4274.37 450.19 N 88.69 E 5987057.01 N 570766.43 E 3.044 439.16 4455.40 35.220 5.610 4272.23 4346.29 499.67 N 94.68 E 5987106.54 N 570771.96 E 2.052 485.66 4550.72 34.980 6.130 4350.22 4424.28 554.19 N 100.29 E 5987161.11 N 570777.05 E 0.402 536.43 ) 4643.67 34.490 5.960 4426.60 4500.66 606.86 N 105.87 E 5987213.83 N 570782.13 E 0.537 585.56 4736.26 34.120 6.720 4503.09 4577.15 658.72 N 111.63 E 5987265.75 N 570787.40 E 0.611 634.06 4830.49 35.150 8.510 4580.62 4654.68 711.80 N 118.73 E 5987318.89 N 570794.01 E 1.536 684.26 4923.29 36.550 11.010 4655.84 4729.90 765.35 N 127.97 E 5987372.52 N 570802.73 E 2.183 735.88 5016.16 37.930 11.790 4729.78 4803.84 820.43 N 139.08 E 5987427.71 N 570813.32 E 1.570 789.74 5104.29 38.360 13.000 4799.09 4873.15 873.60 N 150.77 E 5987480.98 N 570824.51 E 0.978 842.17 5204.20 38.270 12.820 4877.48 4951.54 933.97 N 164.60 E 5987541.49 N 570837.78 E 0.143 901.98 5296.12 37.650 12.200 4949.95 5024.01 989.17 N 176.85 E 5987596.80 N 570849.50 E 0.792 956.47 5389.01 38.370 11.780 5023.14 5097.20 1045.12 N 188.74 E 5987652.86 N 570860.86 E 0.824 1011.45 5481.13 37.710 12.410 5095.69 5169.75 1100.63 N 200.63 E 5987708.47 N 570872.22 E 0.831 1066.05 5573.14 38.340 12.680 5168.17 5242.23 1155.95 N 212.94 E 5987763.91 N 570884.01 E 0.708 1120.68 Continued... 2 June, 1998 - 11:38 -3- Dri/lQuest Sperry-Sun Drilling Services . Survey Report for NWE 02-01 Your Ref: API-500292286600 Alaska State Plane Zone 4 AK Exploration NWE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical. Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) (ft) 5665.63 37.520 12.340 5241.12 5315.18 1211.46N 225.26 E 5987819.53 N 570895.80 E 0.915 1175.47 ) 5758.84 36.890 13.500 5315.36 5389.42 1266.39 N 237.85 E 5987874.58 N 570907.88 E 1.011 1229.89 5851.81 34.850 15.150 5390.70 5464.76 1319.17 N 251.31 E 5987927.48 N 570920.84 E 2.428 1282.81 5940.22 33.110 15.520 5464.01 5538.07 1366.82 N 264.37 E 5987975.26 N 570933.45 E 1.982 1331.02 6039.98 28.950 18.560 5549.48 5623.54 1415.99 N 279.36 E 5988024.56 N 570947.97 E 4.455 1381.47 6131.87 26.530 18.860 5630.80 5704.86 1456.50 N 293.07 E 5988065.20 N 570961.30 E 2.638 1423.67 6224.77 25.070 20.600 5714.44 5788.50 1494.56 N 306.70 E 5988103.39 N 570974.58 E 1.770 1463.68 6318.12 23.850 21.020 5799.41 5873.47 1530.69 N 320.43 E 5988139.65 N 570987.96 E 1.320 1502.03 6410.95 21 .950 21.990 5884.92 5958.98 1564.30 N 333.66 E 5988173.38 N 571000.87 E 2.087 1537.91 6503.16 19.760 23.430 5971.09 6045.15 1594.58 N 346.32 E 5988203.78 N 571013.24 E 2.439 1570.60 6596.13 17.420 25.210 6059.20 6133.26 1621.60 N 358.49 E 5988230.91 N 571025.16 E 2.590 1600.17 6688.78 17.170 29.760 6147.66 6221.72 1646.02 N 371.19E 5988255.45 N 571037.63 E 1 .484 1627.69 6781.85 16.730 34.910 6236.70 6310.76 1668.93 N 385.68 E 5988278.50 N 571051.90 E 1.680 1654.72 6850.33 16.870 39.070 6302.26 6376.32 1684.73 N 397.58 E 5988294.41 N 571063.65 E 1.767 1674.26 6943.17 16.120 40.240 6391.27 6465.33 1705.03 N 414.40 E 5988314.86 N 571080.27 E 0.884 1700.07 7005.71 14.920 40.650 6451.53 6525.59 1717.76 N 425.25 E 5988327.70 N 571091.01 E 1.927 1716.41 7070.45 14.830 41.260 6514.10 6588.16 1730.31 N 436.14 E 5988340.36 N 571101.78 E 0.279 1732.61 7132.20 16.030 42.780 6573.63 6647.69 1742.51 N 447.15 E 5988352.66 N 571112.67 E 2.051 1748.54 7194.08 17.010 43.780 6632.95 6707.01 1755.32 N 459.21 E 5988365.58 N 571124.61 E 1.649 1765.51 J 7256.16 18.090 46.840 6692.14 6766.20 1768.47 N 472.53 E 5988378.85 N 571137.80 E 2.288 1783.37 7317.97 18.930 50.860 6750.76 6824.82 1781.36 N 487.30 E 5988391.88 N 571152.46 E 2.471 1801.69 7409.44 20.700 58.590 6836.82 6910.88 1799.16N 512.61 E 5988409.92 N 571177.60 E 3.453 1829.29 7475.00 21.580 60.850 6897.97 6972.03 1811.07 N 533.03 E 5988422.02 N 571197.90 E 1.829 1849.39 7537.73 22.810 61.190 6956.05 7030.11 1822.55 N 553.76 E 5988433.70 N 571218.52 E 1.971 1869.25 7600.91 23.760 61.880 7014.09 7088.15 1834.45 N 575.72 E 5988445.80 N 571240.37 E 1.564 1890.07 7663.26 24.770 60.770 7070.93 7144.99 1846.75 N 598.20 E 5988458.31 N 571262.73 E 1.777 1911.48 7726.73 26.180 61.090 7128.22 7202.28 1860.01 N 622.06 E 5988471.80 N 571286.46 E 2.232 1934.39 7789.20 27.840 60.840 7183.88 7257.94 1873.78 N 646.86 E 5988485.81 N 571311.13 E 2.663 1958.19 7850.83 28.050 60.360 7238.32 7312.38 1887.96 N 672.02 E 5988500.22 N 571336.16 E 0.499 1982.51 7944.71 28.210 60.060 7321 .11 7395.17 1909.95 N 710.43 E 5988522.57 N 571374.36 E 0.227 2019.96 Continued... 2 June, 1998 -11:38 -4- DrillQuest Alaska State Plane Zone 4 AK Exploration NWE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg VerticaJ Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) (ft) 8037.44 27.840 59.740 7402.97 7477.03 1931.80 N 748.13 E 5988544.78 N 571411.85 E 0.431 2056.95 ) 8130.92 27.720 59.140 7485.68 7559.74 1953.95 N 785.65 E 5988567.28 N 571449.16 E 0.326 2094.11 8224.71 27.510 58.830 7568.78 7642.84 1976.35 N 822.91 E 5988590.03 N 571486.20 E 0.271 2131.38 8317.36 26.780 60.430 7651.23 7725.29 1997.73 N 859.37 E 5988611.75 N 571522.46 E 1.114 2167.37 8411.91 25.460 59.620 7736.12 7810.18 2018.52 N 895.43 E 5988632.88 N 571558.32 E 1.446 2202.65 8505.82 22.830 57.570 7821.81 7895.87 2038.50 N 928.23 E 5988653.17 N 571590.93 E 2.939 2235.69 8600.4 7 20.830 55.840 7909.67 7983.73 2057.80 N 957.65 E 5988672.75 N 571620.18 E 2.219 2266.54 8693.74 17.940 54.780 7997.64 8071.70 2075.40 N 983.12 E 5988690.59 N 571645.47 E 3.121 2294.03 8786.21 16.530 52.420 8085.96 8160.02 2091.63 N 1005.18 E 5988707.03 N 571667.38 E 1.702 2318.72 8817.97 16.390 51.930 8116.42 8190.48 2097.15 N 1012.28 E 5988712.62 N 571674.43 E 0.621 2326.93 8912.58 14.470 54.720 8207.61 8281.67 2112.21 N 1032.44 E 5988727.87 N 571694.45 E 2.175 2349.69 9006.00 10.900 58.690 8298.74 8372.80 2123.55 N 1049.52 E 5988739.36 N 571711.42 E 3.932 2367.71 9100.34 8.580 59.880 8391.71 8465.77 2131.71 N 1063.23 E 5988747.66 N 571725.05 E 2.468 2381.36 9163.22 8.150 59.760 8453.92 8527.98 2136.31 N 1071.14 E 5988752.33 N 571732.92 E 0.684 2389.13 9214.63 8.220 59.740 8504.81 8578.87 2140.00 N 1077.46 E 5988756.08 N 571739.21 E 0.136 2395.36 9314.85 8.670 64.000 8603.94 8678.00 2146.92 N 1090.44 E 5988763.12 N 571752.12 E 0.769 2407.56 9410.60 8.190 63.870 8698.66 8772.72 2153.09 N 1103.05 E 5988769.41 N 571764.67 E 0.502 2418.92 9504.42 7.040 63.970 8791.65 8865.71 2158.56 N 1114.22 E 5988774.98 N 571775.78 E 1.226 2428.99 9599.01 6.080 63.670 8885.62 8959.68 2163.32 N 1123.92 E 5988779.84 N 571785.44 E 1.016 2437.75 \ 9694.44 5.540 65.710 8980.56 9054.62 2167.46 N 1132.64 E 5988784.06 N 571794.12 E 0.606 2445.50 f " 9742.17 5.420 64.810 9028.07 9102.13 2169.37 N 1136.78 E 5988786.00 N 571798.25 E 0.309 2449.13 9815.00 5.420 64.810 9100.58 9174.64 2172.29 N 1143.01 E 5988788.99 N 571804.44 E 0.000 2454.63 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 27.990° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9815.00ft., The Bottom Hole Displacement is 2454.65ft., in the Direction of 27.752° (True). Continued... 2 June, 1998 -11:38 -5- DrillQuest . Sperry-Sun Drilling Services Survey Report for NWE 02-01 Your Ref: APJ-500292286600 AK Exploration ) Comments Measured Depth (ft) 0.00 9815.00 ./ 2 June. 1998 - 11:38 Station Coordinates TVD Northings Eastings , (ft) (ft) (ft) 0.00 9174.64 0.00 N 2172.29 N 0.00 E 1143.01 E Sperry-Sun Drilling Services Survey Report for NWE 02-01 Your Ref: AP/·500292286600 . Alaska State Plane Zone 4 NWE Comment Tie-on Surface Projected Survey -6- DrillQuest ~6' 035" BP Exploration (Alaska) Inc. North West Eileen 2-01 [ [ I I 1 1 I I I I I I I PREPARED BY: Sonic Evaluation using the Dipole Sonic Tool (DSI) Dates Logged: 2 April 98 Depths Analyzed: 2658 - 7382 (md) Data Used: DSI Sonic ~'E'~'E' -!l\~fF[) ',:, c~ (~I "'~ i ~I Œn"",," ' JUL ø 2 1998 Ai_' Oì¡ ,& Gas Gons, Cr;!mmission ~Jiehora~e ,.-'."NEIL C. HEWITT, Scblumberger GeoQuest Alaska April 22, 1998 SURFACE EQUIPMENT GSR-U¡Y DTM-B OOWNHOLE EQUIPMENT LEH-Q i 71.7 Lei-Q DTQ-H CTEM D 68.8 69.5 ECH-KC T~Stæuo ."., =86.5 DTCHo-A ToolStatu DTA-A ~ 66.5 ECH-KE DTA-A SGT-L Gamma Ray _ 61.6 62.5 SGH-K SGO-sA SGD-TM " - DSST-B 57.0 SPAQ-AA ECH-SC SMDR-AA SSIJ.BA SMDX·AA [ I I r\~, \'" ¡ II I _ . I PWF = _8.0 I 11 Tenllio~~t I 0.0 TOOL ZERO MAXIMUM STRING DIAMETER 3.63 IN MEASUREMENTS RELATIVE TO TOOL ZERO AlL LENGTHS IN FEET AH-)oo{ AH·XJO( GPIT-A;B GPIQ-AO GPIH·A I [ ( ¡','. ~ Date Logged: Depths Analyzed: Data Used: 2-APR-98 2658 - 7382 ft (md) DSI Sonic Upper Dipole Lower Dipole and P & S and First motion modes Purpose of Reprocessine: Reprocessing of the three modes of the DSI tool were made across the logged t determine: · Compressional Slowness · Shear Slowness. · VpNs and Poissons Ratio. Enclosures: This Discussion references only NfEASURED DEPTH Included in this report are:. · 1/500 scale Profiles derived from the various modes. Introduction The NEW 2-01 wellbore traverses a series of shale and sand bodies over the interval. 13 3/8" casing was set at 2664 ft after drilling to that depth. 12 ~" bit wa used to drill to TD 7476 ft (drillers depth). The DSI run was made over this openho section. Bottom 100 ft of well was not covered. In the shallow portions of this well, the shear slowness is slower than the mud wav slowness (about 189 us/ft). Shear slowness from the Dipole mode is unaffected whi the P&S mode is unable to propagate the Shear wave at velocities near or slower th the mudwave. The P&S mode can resolve only the P wave in this well. The eight waveforms are reprocessed for each of the 3 modes and a set of Slowness (Dt) curves are computed. The processing sequence for each mode is 6.0 1. Filter waveforms 2. Slowness Time Coherence 3. Peak Energy Labeling 4. Label Edit 5. Borehole Compensation 6. Post Processing 4.0 The first 3 steps are now done in the MAXIS field unit. Peak Energy waveforms ar processed in the GEOFRAME software to correctly label the waveforms. I l I l I [ l I [ [ - 2600 ,I;', ':"'>'>J:,:!,l~~';~,\~ :\::,;'~ì',!~~W.!:):}\i-!_ _I' 20ð4?O (u:. ' ,.,,3 20¿4:J (u:.' " ~ '. 'i"" ,"'ì{'~·;*1,,~I~~,.:;('r,f.I:I,((A:~,';f ... 1 ; 500 (m) 0 t-lItp.rP.:1 W ;.q'\·~nrm In:11 Jt W R~/p.t:1rrn .' , ..' .," - '." ~._"'...'-.----''''----~-.''.--.----.-.~''''-'''''''-'''~_.''-.--."''---..._--_._-.....--.._---_.--,---_.._-,._,_...__.._._.,_._-~ ,'. . '". .".'" ....... ."""" ...., Example: DIPOLE MODE 1st waveform, before and after filtering 1. DIPOLE Waveforms: 1 - 3 kHz WINFIR low frequency bandpass filter 2. P&S waveforms: 5 - 15 kHz BUTTERWORTH bandpass filter The raw waveform data is treated in the field to remove noise for each of the logging intervals. This was not re-filtered in the computing center 1. Filterin~ :( ( (' ( 2. Slowness - Time Coherence 80ft Fcrma1ion- Meno p:wle Slowness Time Coherence is applied to the waveform data from the 8 receiver array for each mode. The receivers are spaced 6" apart on the tool so the sonic energy arrives slightly later at each sequential receiver. ~ t~"'" -., .. ,- - ---...... I' ... . Tim~(i)~~~ ~. _ The set of waveforms are sequentially time shifted and stacked. Slowness (~t) vs Time for a single depth - showing the Energy of Stacked waveform Maximum Energy indicated by Blue Arrow ]0 ]0 50 JO Slowness (~t) 50 50 Time (T) The resulting energy spectrum is relabeled and manually edited to generate a pair of slowness curves for each mode: · DT Compressional · Dt Shear · DT Shear Monopole P&S DIPOLE Monopole P&S Receiver Array/ Transmitter Array Receiver Array / Transmitter Array Receiver Array/ Transmitter Array (DT Compressional 'First motion Detection' is not based on STC) (' (' Slowness - Time Projection vs. Depth (P&S - Receiver Array in casing and below casing) DTCO (baehole eorr.) 160 (LSIft) __E~~~~s-=-R~~~~___ 160 (LSIft) - - - - - ~!- ~~~ .?!~~~._"!: >: ~- ~~~ - - --- 160 (uslft ) _____~~3..~0~~_____ ..g) o (mV) __..._~J~~!?~!~] _ '.,_ (~PI) "_ ;5 ~ ¿. .> I ~" c~~~ ~. .;! -~$- :"~ l 1 r"~ j l l I f ( i ;- -",0 ~-,( l' ;j, , 1 { }..,.¿ I t ~=~__'¿~ -;S=:=:;..."_~ ~,oJ 0..:::-' t" :;:-=- ~~ ~-:-?- '-', 'I "" /' " r. .... "- -~( ! .[~*~~~,I ¿.~ ';~f~ ~X'>' ì .. t ( J ¡ f ,Ì ~ -.,' : . ~ 00 00 DT Com press. T x m ode Shear Transit Time - "_.-"_._~,-_.,,..- .". 00 40 240 0 :DJO ( usAt) __ _ __~~ ~ e~~_s.:.~_:.c_ ~ ~~~_ _ _ __ (us) Compress. Trans~ Tim e 20 40 240 0 ( usAt) 1 . 500 str"~i~~L;~~~.~, I',,~~ 150 . (ft) 40 240 0 :!JOO (us) Fi~ered Wavefam ":-,'1.' ::;~',;!'L\','li~!';"i;S:~i:~~~~? h } ~ \ ~-- ¡ t 1 í j ~ ~ 0000 2500 ";hl :¡¡ "ii~\ ¡1 I,; I,'," 11, r~ .~~f I~ I .-'" ¡,; ~", '.¥ , , ~ I ,~, I", 2550 ,I '~' ,<, ",1 "" 2600 0", . ~~;~'¡~ "',~'~~> '".1 "t·' ; . 111._--1: ~ . ~ 1.~" ; 'Þi'1 : !'~"~"! ~J¡ .:,'$,1 !'Io!,~, --..,. ~ I .... : ',:: I~ 'J 2850 ~... : I ; \... 2700 ,I i I ,;<. ¡.., '1 ..¡ ! í .~ I ~ " I , ,~ . ::~ I' ~ ':.~: (" (" 3. Peak Ener~y Labellin~ The Peak coherence points (Blue Arrows in the Crossplot) for each 6" depth increment are shown as Tadpoles in the STC Result Database Display area -, -'-)- -.,-,-- ::I 775 (us/ft) 75 DT2A .PTE .UDP .200.SWP .STC.R Edt area ::r DT2R .ITP .UDP .200 .SWP .STC.R 775 75 775 75 1 : 100 (ft) 775 (us/ft) DT2R .ITP .UDP .200 .SWP .STC.R (us/ft) DT2R .ITP .UDP .200 .SWP .STC.R 75 776 76 (us/ft) t1 ..J ;', 2000 7000 " ,,::1 ',",,", 4. RELABEL Process Expanded scale log, shown with Peak Coherence points as Tadpoles, and the computer generated Interpolation line (Left Side -Black Line). The Analyst may choose to override where data is sparse (Right Side - Pink Line). ( Borehole Compensation ( The STC Algorithm has 2 methods to derive slowness. The first is Receiver Array, which consists of determining move out, or coherence, of the eight receiver waveforms at a given transmitter position. The other is Transmitter Array. Once the tool has been run, one can determine the eight positions of the transmitter which correspond to the previous receiver positions and rerun the process. The receiver and transmitter modes are affected in opposite directions when the borehole size changes. Hence the average of the two is approximately 'borehole compensated'. For the DIPOLE mode, a slight bias is applied to each raw DT. The DSI measures a flexural wave which is dispersive and must be corrected to obtain true formation shear slowness. Relabelled DT curves - Transmitter Mode and Receiver mode averaged to obtain BHC Shear DTs and BHC Compressinal DTp o PR.FIN ---------------------------------------------------------------------- 1.S ( ) .......... ......... ...... _............... ....._..__._ .Y.F:Y.f?:f. !~_. _ n__ ___ __ __ _.n _ _.... _.. _..".. _ .__n_. ..nn_ _"...".._ ( ) DTSM .LDP . CRC .SHC ~ .",,:. ~."".. c~~,~' ~-~: "~}',"'" -~,: ç~, <1 "",;~ ¿? '. --.-------~:~~:~ ,~~ ~ -........---.. "~ ~ '.~ ~ .,,"...~~' '" ) ~" } ~.:::'''''..~ ~ 440 440 .','. .~.Jf'c:~.?~..~,::':L.., o 3.)0 (~PI) 1 : 600 ft 240 (:1 ~ij '.. I ".~.:".. _' 5'''~:J::!>O .___ C'-' -' ;JJ..-' (::B~ ~..-t __,"- ~~...~..: ~~ ~,).. j ~ #..1' 2500 ¡ ¡ ¡ I I I I .. _.. .:-::": :,..... , ;;r ......... ".---~ --= --~ ':.':... ,:....:;...:..,. -- .".n L....-........ :~:.. ~ ....."..~... ~,i",~_'::c ~ ... .. M ~ R ~..-: ... '" ' "t- " ,...- ) -t..'"-- ,~. ...., 2550 2600 " , i .., ~. ~ 'I~, "...... r,,;, I 2650 " ~\ 2700 as .!D ( uS/ft ) DTSM .F IN (Upper Dipole) 40 40 ( usJft ) -..:..:::-.... ...': .._---~;. ......:":... ._~~~~ ~~ -: :~~:.-..~ _.¡~~~~.. .~- I I 1 1 I 1 I 1 t \ SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS Anchorage, Alaska cp~'o?:>ç FINAL ADT WELL SUMMARY REPORT BP EXPLORATION NWE 2-01 Northwest Eileen Prospect North Slope, Alaska 1 I I 1 1 1 I I I I Final Report Summary May 1998 PREPARED FOR: BP EXPLORATION PREPARED BY: John Patton Sperry-Soo Drilling Services Logging Systems Anchorage, Alaska I I I 1 1 1 1 I I [ [ [ 1 I 1 1 I 1 I ( ~: TABLE OF CONTENTS Introduction................................................................................................................... ........... A Well Diagram............................................................................................................................B Well Summary By Intervals..................................................................................................... C Conclusions ............................................................................................................................. D Graphical Analysis. ................. ..... ... .... .... ......... ........... ........... ............ ....... ..... ...... ............ E & F Well History:..............E 1) Days Drilling 2) Rotating Hours 3) Bit Hours 4) Bit Footage 5) Torque 6) Time Distribution - Hours 7) Time Distribution - Percent Allocation Pore Pressure Evaluation:..............F 1) Pore Pressure - Mud weight - TVD 2) Condensed Resistivity - TVD 3) Condensed Pressure Parameters 4) "Dc" Exponent - TVD Log Pacl(et .............................................................................................................................. . G 1) Engineering Log (250'finch) 2) Condensed MWD- TVD Log (250' finch) 3) Data Disks Bit Record........................................................................................................................ ........ H Drilling Mud Record................................................................................................................. I Survey Record ........................................................................................................................... J 1) Survey Data Show Reports......... .... ..... ........ ........ ........ ........ ......... ....... ................... ..... .......... ........ ...... .... ..... K 1) Show Reports - Zones of Interests 2) Pixler Paper - Reference Material ADT Morning Reports...... .... ..... ... .... .... ... ... ........ ........ .................... .... ..... ...... ..... ........... . ......... L I r r I 1 ( 1 I I ( ( ,II: , INTRODUCTION Drilling operations for Northwest Eileen 2-01 were initiated 03-10-98, by BP Exploration - Shared Services Drilling. The well was drilled by Pool Arctic Alaska's Rig 8 on an ice pad in the extreme northwest comer of the Prudhoe Bay Unit. The ice pad was constructed earlier in the season in Section 19, Township 12 North, Range 11 East just off the Milne Point road. The well was planned as an appraisal well to evaluate the potential commercial value of a development pad near this location. NWE 2-01 was drilled to a total depth of 9,815' on 4-18-98. The total number of operating days that was required to reach this depth were 40 days including the spud in date. Operations to plug and abandon the well were initiated 4-20-97, after completing MDT fluid and pressure tests for the 8 1¡2" section of the well. A Sperry-Sun Logging Systems LS2000 Unit was in operation from surface to TD providing full Inud logging and applied drilling technology services. The 2000 Unit and crew provided assistance in the drilling of NWE 2-01 by monitoring essential drilling parameters and gas levels. Also provided were fluid hydraulics information, pore pressure vs. necessary mud weight evaluations, and a wide range of geologic interpretations and sampling services. Additional services included the integration of real-time Gamma Ray and EWR information from data supplied by a separate Sperry Sun MWD Unit. r 1 ( 1 The following pages of this report are designed to supply concise historical data of the events that occurred on NWE 2-01, along with some analysis and recommendations for specific problems that were experienced during different sections of the hole. All of the information compiled in this report was acquired and recorded by the LS2000 Unit at the well site. The sensors incorporated in this unit are independent from the rig sensors and may differ slightly from those reported by the rig contractor. In addition, any evaluations in this report regarding formation evaluations, pore pressure estimates, or other geologic interpretations are made entirely by Sperry-Sun personnel from examination of the data collected by the LS2000 Unit and reference Inaterial made available by the Operator at the rig site. SAG RIV ER SHU BLn: IVISHAK MILUV EACH KUP ARU K "C II HRZ TOR OK "EST SAK - SCHRADER BLUFF UGNU BASE PERt1AFROST (~r w£LL DIAGRAM / Formations - --¡.. -; ""'-F - "-"-"L - - - ~-~~_..- -- ··-··r - -t·ler.·.'.·,',·. . ,. . "I · . I· - . . -t. . ~'Ir.::J"::Jr.::Ic::Il:::tr.::ll:::t 1::3 '. . . . .'. . .' .' .' .' . - 1:::1.·.·.·.·.·.·.·.·. ..-...-. VVI "ï"-''-' "'/ "'/ 'v -~_. . - , . - .~ '.,/'1,/"'/- - -.-. "'/ "'/"';' - - - - ',,("'('.,(- - -- "/~'I" ---- ",/"./ .-.. ,,-- ".,,-~--' "./'1, __.._.1:::1 '.,/"'/___' r.::I "Y':-':':-'-'~"'--~ . . ." :-: ''0/- ---'. ~'".. .-.-. , ..- . , - . . , . . _ .._.._.1:1.... __.._.. CI·.·. . . . . . - ...-. . . . . . -.-..-..-. _ _''"" ._. '"_",_, C _ ""_.._··I:'''J -- ...-..-..- ':"":":-:- ~~. ~ ~ .~ ~ .[ ~~~~ ~:-:~ :-:~'r.~ -..-..-. .-..-. ~,~::-:'~: ~~~ ~~~~:~ . . . . ~~~=~=~=::~ 9 5;'8·· CASING AT 9276' 8.68·· ID - 'A7 LB/FT 8 I/Z·· HOLE TO TD , . ra . '.·.·u - _. - - - -. - - 0'00'00 0 '.oo'r-,o,~P '00.(' . .... 7§'oa'oa- ~..., ' 0, a " . .' .. 0' /'" :_.:-:,,:-: . a'ÇJa- - . . " . Litho logy 20" CONDUC TOR AT 110 19_1"' ID - 94- LB.lFT ( B.P. Exploration NORTH ~[ST [IL[EN 2-81 Casing Progra1Ð "".,,:"'''''''+''''''.'''''''''. 9888 ...",,,,,. "'...""""".""..." ......M................................ 8888 -"'"~",,..,,""""'''''''' t... [ 1 1 1 I I I I 7880 """",,.. "'''''''''''''''''''''''' .........,..,...,.............,..'.....,. 6888 "'-'''''''-''-'''''''''''- ......._.."......'.....M.'''''....... S800 -"",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 4M..M.......,...._....M.M.......... nD I 1 1 I 1 I I [ 1 [ 1t888 ...""-",, ...""""""." "",.. ·"''''''''''1'''''''''''·''''''''''' 3000 ."",-,,,,,,"""'."""'."" .-- ...--.............-. ....... 2888 ~,,-"'''''-'''''''''. ------ 1ÐØØ _L.."",,__._..,_. I I n en I.Q 1 6 f V. t-tt= COM co""d ~I-'J :z: I 1 I' 1 1 1 1 1 I I [ 1 I f ( WELLSU~ARYBYINTERVALS Interval: 110' to 2,680' Days: 8 Average WOB: 10/25 klb Hole Size: 16" Average RPM: 125 No. Bits: 1 Average GPM: 680 gpm Rotating Hours: 25.2 Average SPP: 2900 psi Deviation: 0- .62 deg Average ROP: 102 ft/hr Mud Weight: 8.7-10.6 ppg Mud Type: Spud Mud Pool Arctic Alaska's Rig 4 was positioned on location prior to the spud in date of 03-10-98. Structural 20' drive pipe had been set to a depth of 110'. After completing an extensive rig up, a surface diverter system was installed and tested. Drilling operations were initiated by drilling out the structural casing with Bit No.1. Penetration rates for the first bit run were somewhat slow while drilling through the Permafrost in mostly gravel and sand. Gravel drilled in this formation was not very large in diameter and did not appear to slough. The mud weight was gradually increased beginning at 1,000' to a weight of 10.2 ppg bY' 1,500' in anticipation of drilling into hydrates expected in this area. An 8 stand short trip was performed at 1,493' to condition the hole. The estimate for the base of the Permafrost was logged at approximately 1,700'. Gas hydrates were encountered just below this threshold beginning at 1,790'. Moderately high background gas readings averaging 1100+ units were logged while drilling the remainder of the 16" interval to 2,680'. Although additional gas sands were encountered deeper in this section, the primary zone that appeared to be the cause of most of the gas readings was located between 1,790-1,840'. The last 250' of formation drilled in the 16" interval was logged as claystone mal<ing the 2,680' depth a good location for a competent casing seat. Electric logs were not needed for the 16" hole section. 1 1 I I I A low gravity solids problem developed while drilling clays in the lower part of the interval causing the weight to increase to 10.6 ppg. This was a product of not being able to dilute with water (no vacuum trucks were available) and part of the rig's solids control systems had failed (de sander - desilter). The mud system was diluted with fresh mud and water before conditioning the hole with a wiper trip for running casing. The maximum trip gas recorded from this trip was 1205 units. 13 3/8" - 68 lblft casing was run to a shoe depth of 2,664' . The casing was then cemented in place. I 1 1 1 I I I I 1 I I I I ,,11',,1" ~ This interval of the well is believed to be near normal pressure. Moderately high background gas and connection gas readings were logged after penetrating into gas hydrates starting at 1,790'. These gas readings were believed to be associated with melting hydrates rather than free gas bleeding into the well bore. A gradient of 8.5 ppg was estimated for the Permafrost section. This estimate was raised to 9.2 ppg at 1,790'. The estimate was reduced to 9.0 ppg relative to the clay fonllation at the casing seat. The average mud weight used below the Permafrost was 10.2-10.6 ppg and appeared to provide for an adequate overbalance condition to stabilize the well bore. 1 1 I I I I 1 1 1 r 1 1 ( I 1 I 1 r 1 I 1 1 1 1 ~ (' Interval: 2.680' to 9280' Days: Hole Size: No. Bits: Rotating Hours: Deviation: Mud Weight: 27 12.25" 9 169.2 .22/38.37 deg 8.8/10.2 ppg Average WOB: Average RPM: Average GPM: Average SPP: Average ROP: Mud Type: 40 klb 160 725 gpm 3000 psi 39.0 ft/hr KCL Poly Discussion: The blowout preventer stack was nippled up and tested. Additional time was needed to complete repairs to this system and get a proper test for this 5,000 psi stack. The 13 3/8" surface casing was tested to 3,000 psi for 30 minutes prior to drilling out of the casing cement with Bit No.2. Bit No.2, a 12 l;4"bit, was used to drill out of the 13 3/8" surface casing along with 10 feet of new hole to 2,690' on 3-18-98. The hole was then circulated with 9.3 ppg KCL Polymer mud in preparation for running a leak off test. The test that was performed at this depth yielded a fracture pressure equivalent to 12.5 ppg. The 12.5 ppg value observed at this casing seat is normal for this area of the North Slope. Bit No.2, run on a directional assembly with a 1.5 degree motor, was used to drill ahead after completing the leak off test. The directional section of the hole was started after getting the MWD tool far enough out of the surface casing to escape magnetic interference occasionally sliding to correct the angle and direction. Penetration rates for this bit run were good. The angle of the hole was gradually built to 34 degrees by 4,350' and reached a maximum angle of 38.37 degrees from a survey taken at 5,389'. The hole angle was changed from 6,000' gradually reducing the average angle to 18 degrees by 6,600' as per directions in the well plan. High background gas readings were first encountered from two sands drilled in the U gnu between 3,575' -3,675'. Chromatograph breakdowns of the gas encountered in these sands were predominately methane. Hydrocarbon shows that were logged in the sand from 3,625'-3,675' indicated the presence of low gravity oil. A short trip was made at 3,689' to condition the hole pulling the bit back to the 13 3/8" shoe. After drilling ahead, the maximum gas recorded from this trip was 135 units. The pore pressure estimate for the Ugnu Formation was reduced to 8.5-8.7 ppg relative to the lack of connection gas and the low short trip gas reading. High background gas readings continued while drilling in the Ugnu Sands. The mud weight was raised from 9.3 to 9.5 ppg around 3,875'. 1 I 1 1 r 1 I I I 1 r 1 I [ 1 [ 1 [ I (' (" A significant change in the type of background gas was noted after drilling through a bedded sand at 4,075' -4, 115'. Chromatograph breakdowns from high background gas readings from this zone contained good quantities of ethane though pentane. In addition, shows of oil fluorescence itnproved considerably and indicated the presence of lighter gravity oil. High background gas and good quality oil show wen~ logged in the remainder of the West Sak - Schrader Bluff Formation The lithology changed to predominately siltstone below the sands in the West Sak - Schrader Bluff F ormation. Connection gas was also recorded in this change. A 16 stand short trip was performed at 5,176' to condition the hole. The maximum gas reading from bottoms up was 760 units along with abundant clay noted at the shakers. The pore pressure estimate was raised to 9.0 ppg to reflect the change in gas parameters and hole conditions for the Seabee formation. The estimate was again raised to 9.4 ppg after penetrating the K-5 marker and into the Torok Formation. Bit No.2 was used to drill to 5,939' through mostly siltstone with thin interbeds of tuff and then pulled out of the hole. Drilling continued with Bit No.3 in shale. The maximum gas recorded from the trip at 5,939' was 1 ,260 units with 10.0 ppg mud in the hole. In addition, continuous connection gas readings almost double that of background were present below 6,200'. The pore pressure estimate was gradually raised to reflect the change in gas parameters to 9.7 ppg by 6,615', the approximate depth for the K- 2 Inarker (HRZ). Bit No. 3 was used to drill to 6,847'. This bit was pulled out of the hole to change the bottom hole assembly in order to place the MWD tool closer to the bit. This modification was done to assists the geologist in picking the core point in the Kuparuk "C" Sand. The BOP Stack was tested on this trip. Some reaming was required to get back to bottom reaming from 5,240-5,333' and 6,745-6,847'. The maximum trip gas reading recorded while drilling ahead in Kuparuk age shale was 950 units. Core point was decided using real time MWD data and correlating with logs from nearby wells. Bit No.4 was pulled out of the hole at 7,034' after displacing the hole with fresh KCL Poly - 10.2 ppg mud. Two cores were taken in the Kuparuk "C" interval from 7,034' -7066' and 7,066' -7,095'. The total recovery from both cores was 26.5' and 29' respectively. Low background gas and trip gas readings averaging about 260 units for both trips were recorded while coring. The pore pressure estimate for this zone was 9.8 ppg. Bit NO.4 was again run into the hole and used to drill the rest of the Kuparuk Formation. Shows of oil fluorescence were present in the cuttings from this zone but overall gas readings were low. Bit No.4 was used to drill to 7,476' occasionally sliding to turn the hole angle to meet the lower target. I I 1 1 1 I 1 1 I 1 I 1 ( ( This bit was pulled to run electric logs. The decision to run logs was made at this time, rather than at the 9 5/8" casing point, to minimize exposure time for shales in the following Miluveach and Kingak Formations. Additional circulating time was spent in conditioning the hole for logs and included pumping high viscosity sweeps and spotting a shale stabilizing pill on bottom. Considerable difficulty was encountered while running electric logs as the tools would not go past 5,350' on any of the initial runs. After completing the required log runs for the top section of the hole (2,664' -5,300'), an attempt was made to log the lower section using drill pipe conveyed tools. This attempt proved unsuccessful and required a trip in the hole to ream tight spots below 5,200' with a 12 1/4" hole opener. Electric logs were then completed for the lower section after spending approximately a day reaming and opening the hole. Bit No.6, a PDC type bit, was run into the hole. After getting back to bottom, the PDC bit would not drill and was pulled out of the hole at 7,490' penetrating only 16' of fonnation. The bit came out of the hole "balled up" with clay. Bit No.7 was run in the hole and used to drill ahead. A bit balling problem was also encountered on the start of this bit run but was solved by pumping a pill containing walnut hulls, soap, and Sapp while working the bit. Bit No.7 was used to drill to 8,375' penetrating the top of the Kingal( Fonnation around 7,800'. This bit was pulled out of the hole to work on the Rig SCR panel and replace a defective draw works traction motor. Another problem was encountered on the following bit run. Bit No.8 drilled with relatively slow penetration rates and failed prematurely after drilling for only 16 hours. After experiencing high torque conditions, Bit No.8 was pulled out of the hole at 8,860'. Upon inspection at the surface, this bit was graded with extreme wear and broken cones leaving pieces of the bit in the hole. I 1 1 [ I [ Bit No. 9 was then used to drill to the interval total depth of 9,280' in the lower K.ingak. Penetration rates were also slower than expected for this bit run probably because of early damage to the bit frol11 drilling on junk at the start. This part of the well was judged to contain the highest estimated pore pressure for NWE 2-01. The estimate was raised to 10.2 ppg relative to analysis of trends noted on the Dc Exponent and Condensed Resistivity plots. 10.5 ppg mud weight was used to drill the lower IZingale Two wiper trips were made to condition the hole for casing with 10.6 ppg mud. Tight hole conditions were experienced at the very bottom of the hole and at 8,500' - 8,700' on the first trip. The second short trip was needed to effectively conditioned the hole. 9 5/8" - 47 lb/ft casing was then run to near bottom at 9,276' without encountering problems. This casing was cemented in place using a two stage cement job. Additional time was needed on this cement jog to repair a I I [ 1 1 I 1 I I I I (' It washed out surface line on the rig. Full mud returns to surface were recorded while running casing and pumping and displacing the first stage cement. Approximately 150 barrels of mud were lost to the fonnation while displacing the second stage. Seven show reports were completed for this section of the hole and included evaluations for the Ugnu, West Sak - Schrader Bluff, and Kuparuk Fonnations. Oil shows of fluorescence and cut were recorded in drill cutting samples collected throughout these zones of interest. Analysis from gas readings and cuttings fluorescence taken in the U gnu indicated the presence of low gravity oil in the lower part of this fonnation. This evaluation changed after penetrating into the West Sak - Schrader Bluff which appeared to contain better quality oil. Good quality oil shows were logged in this fonnation. The Kuparuk "C" Sand, one of the primary targets for NWE 2-01 drilled in this interval, also appeared to be oil bearing. Please refer to the Conclusion and Show Report Sections of this report for additional analysis. The lithologies of this section consisted of gravel, sand, clay, siltstone, sandstone, coal, and thin tuff beds. No abnormal gas readings were encountered, however high background gas readings were logged in the Ugnu and Schrader Bluff Fonnations where good hydrocarbon shows were prevalent. The pore pressure estimate for this section of the hole ranged from 8.7 to 10.2 ppg establishing an increasing gradient below 5,500'. Hole problems for the interval were moderate and were mostly associated with problems encountered while trying to run wire line logs. Moderate amounts of drag were noted on trips through the lower section of the hole in the Kingak F onnation prior to running casIng. I 1 1 1 [ I I I I 1 1 1 I I 1 I 1 1 1 1 1 1 1 I I I ( f Interval: 9,280' to 9,815' Days: Hole Size: No. Bits: Rotating Hours: Deviation: Mud Weight: 5 (to TD) 8 1/2" 3 26.0 8.2 - 5.4 deg 9.6/9.7 ppg Average WOB: Average RPM: Average GPM: Average SPP: Average ROP: Mud Type: 11/25 klb 90/1 70 367/450/ gpm 1100/3100 psi 20.5 ft/hr KCL Poly Discussion: The blowout preventers were tested prior to running in the hole with Bit No. 10, an 8 1/2" bit. The ES cementer was drilled at 7,416' and the top of the first stage cement was tagged at 9,186'. The 9 5/8" casing was then pressure tested to 3,500 psi and successfully held at that pressure for 30 m.inutes. Bit No.1 0 was used to drill out cement, float collar, and casing shoe along with 20 feet of new formation to 9,300'. A formation leak off test was taken yielding a pressure equivalent of 15.8 ppg. The hole was then displaced with fresh 9.6 ppg KCL Poly mud in anticipation of coring the Sag River Formation. The mud weight was lowered to 9.6 ppg to minimize overbalance on the expected lower fonnation pressure in the Sag before pulling out of the hole with Bit No. 10. A 90 foot core barrel was made up on Bit No. 11 and run into the hole. Core No.3 was taken from 9,301 - 9,391 recovering 90' of core from the lower Kingak, Sag River Sandstone, and the Shublik Formations. High background gas readings were observed during the core run below 9,340' reaching a maximum value of 1,985 units. The pore pressure estimate for the Sag was reduced to 9.0 ppg using overall gas readings and pressure test information from nearby wells as reference. Bit No. 12 was run into the hole after laying down Core No.3. This bit was used to drill the remainder of the Shublik Formation. The pore pressure estimate was raised to 9.4 ppg for this formation relative to gas readings and historical data. Drilling continued with Bit No. 12 through the Eileen and into Zone 4 of the Ivishal<. Moderate background gas readings and fair shows of fluorescence were logged from 9,575' to 9,625'. Oil shows and gas readings were considerably less prevalent below the 9,625 depth. Bit No. 12 was pulled out of the hole at 9,815', the total drilled depth for NWE 2-01 on 4/19/98. The hole was condition with a wiper trip and extra circulation time in preparation for running a single logging run using an MDT to collect fluid samples and pressure data. The logging tool was run drill pipe conveyed completing logging operations on 4/20/98. The well was then plugged and abandoned. I I 1 1 1 1 I I I I I I 1 1 1 I I I I I( A total of four show reports were filled out for the 8 1/2" interval of this well relative to the targeted zones of interest. The show reports were filled out for the Sag River and Ivishak Formations. Oil shows of fluorescence and cut were recorded in drill cutting samples collected in both intervals. In addition, ratio analysis from gas readings taken in these zones indicated the presence of light gravity oil in the Sag River and medium gravity oil from a section in the top of the Ivishak. Shows diminished significantly after penetrating into the oil water contact in the Ivishak estÌ1nated at 9,620'. The lithologies of this interval consisted of siltstone, limestone, shale, and sandstone. Hole problems for the interval were minor. The 9.6/9.7 ppg mud weights used to drill this section provided sufficient overbalance to safely drill through the observed pressures. I 1 I I 1 1 I 1 1 I (' ( CONCLUSIONS GENERAL: The drilling program for Northwest Eileen 2-01 was designed to penetrate to an estimated measured depth of 10,000' and evaluate two formations identified as primary targets for this well. NWE 2-01 was drilled to 9,815 in 40 days. This amount of time was significantly over the planned time interval of 23 days. Initial plans called for testing the well through a 7" production liner. The original plans to test the well were canceled because of time delays pushing the operation too close to breakup. The planned time interval, a reasonable estimate for this job, appeared to be made using comparison data with wells drilled at Prudhoe Bay using an average production rig. This time interval proved to be too optimistic given the start up condition for Pool Rig 8. Simply stated, Pool Rig 8 did not perform as well as any rig rwming in the field. This was a newly assembled rig with a number of inexperienced people. The rig crews encountered numerous equipment problems that required additional rig time getting an assorted number of systems in working condition. Minor hole problems that were experienced in the first interval of the well that consisted of moderately high background gas encountered while drilling through hydrates and low gravity solids build up in the mud system. The gas hydrates drilled on this well did not cause adverse problems. The low gravity solids buildup was primarily caused by faulty solids control equipment. I I 1 1 1 1 1 I In the deviated section of the hole, the angle build and direction was performed adequately as only Ininor amounts of drag were experienced on trips. The probable causes for the drag were swelling clays and some wall cake buildup in sands. The short trips employed while drilling this section proved to be an affective means to clean and condition the hole. The kick off point for this well was started in the first well bore interval below 2,750'. From here, the hole angle was gradually built to an average of 34+ degrees at 4,300' and later dropped to 20 degrees before entering the Kuparuk target. The hole was then turned to the right crossing a fault in the Kingak Formation and dropped to 8.2 degrees before reaching the 9 5/8" casing point. Good penetration rates were observed on the first two bit runs extending to about 6,000', while slow drilling rates were predominate for the rest of the well. One bit failed to drill because of balling problems in a clay rich formation. This bit, Bit No.6, was a PDC type bit and could not appear to get started without balling up. The next two bit runs did not perform as expected averaging only 30 on bottom hours per run before failure. Bore hole washouts were prevalent in 1 ( 1 1 I 1 I I 1 1 1 I 1 I 1 1 I I I ( (' the 12.25" hole interval because of slow penetration rates combined with relatively high flow rates and more than expected trips with additional circulation time. Another hole problem in the 12 ';4" section was associated with trying to evaluate the hole section above the Miluveach Formation with electric logs. The tools would not go below 5,300' though a siltstone/shale section that we believe to contain ledges associated with washouts. One attempt was made to run drill pipe conveyed logs that also failed to get past the 5,300' zone. This area of the hole had to be reamed with a hole opener to properly condition the hole to allow wire line tools to pass. As a result, the extra trips and other rig operations caused an additional two days of rig time for logging in the 12 ';4" interval. PORE PRESSURE: Pore pressure estimates for this well were made generally from observing overall mud gas readings relative to the current mud weight in conjunction with analysis of trend data established by resistivity and "Dc" Exponent data. NWE 2-01 appeared to be near normally pressured extending from the surface to 5,000' TVD. Using the Condensed Resistivity Data and Dc Exponent Plots (refer to Section F) for reference, the beginning of an increasing pore pressure gradient is believed to start at 5,300' TVD. Pore pressure estÎ111ates were steadily raised to 9.4 ppg near the bottom of the Seabee Formation and the top of the Torok. An estimate of9.7 ppg was made for the HRZ drilled between 6,300'-6,400' TVD. The pore pressure appeared to decrease slightly after drilling below the Kuparuk in the Miluveach Formation relative to gas readings in this zone. The estimate was then increased in increments in three separate shale zones in the Kingak where resistivity readings approached one ohm-meter. Analysis of trends on the Dc Exponet Plot, while using a pore pressure overlay, also supports the premise of over pressure in the low resistivity shales. Dc Exponent analysis was the primary quantitative reference employed in establishing an estimate of 10.2 ppg in the lower Kingak. The pore pressure estimate was reduce to 9.0 ppg in the Sag River Sandstone. The references used in determining this estimate were the observed overall gas readings while drilling with 9.6 ppg mud and offset well pressure test data. The pore pressure estimate was again raised to 9.4 ppg upon penetrating the Shublik and Ivishak formations based on the same type of evaluation. An estimate of 9.2/9.3 ppg was made for the water leg of the Ivishak Formation at the bottom of the hole extending below 9,625'. I I I r I- I I I I I ( ( ZONES OF INTEREST: Shows of oil cut fluorescence were first noted on the mud logs from depths beginning around 3,525' in the Ugnu. These shows lacked primary fluorescence color and intensity. Although high background readings were recorded in the U gnu Sands, chromatograph breakdowns of trap line gas readings were predominately methane. This type of fluorescence, combined with relatively low recorded amounts ofC2-C4 gases, indicated the presence of heavy oil in the Ugnu sands. Very good shows of fluorescence were logged in the West Sak - Schrader Bluff beginning at 4,075' extending through individual sands to 4,745'. Sands logged in this zone had much better quality of primary fluorescence, high background gas readings, and very good ethane through pentane values from chromatograph analysis of the background gas. In our opinion, the presence of the observed good quantities of C2 - C5 is a good indicator that the oil in this zone has not undergone the same degree of bio-degradation as the oil found in the U gnu. The West Sak - Schrader Bluff Sands on this well appear to contain good quality oil. One of the primary targets for this well was the Kuparuk C Sand. The better part of this sand was logged between 7,045'-7,088'. Although analysis of the gas readings and fluorescence from this zone also indicated that the C Sand was oil bearing, from our perspective most of this zone appeared to be tight. I I r I I I I I Good oil shows and high background gas readings were logged in the Sag River Sandstone from 9,338' -9,375'. Analysis of overall oil fluorescence and chromatograph readings indicated very light gravity oil or possibly condensate in the top of the Sag between 9,338'-9,350'. The lower part of this zone, extending to 9,375', appeared to contain somewhat heavier oil estimated to be in the 35 gravity range. Very poor gas readings and oil shows were found in the Eileen; however, the top of Zone 4 of the Ivishak appeared to contain oil beginning at 9,576'. The oil water contact in the Ivishak was estimated at 9,620'-9625' from analysis of resistivity and background gas data. 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EXPLORATION WELL NORTHWEST EILEEN 2-01 LOCATION SEC 19 - T12N - R11E CONTRACTOR POOL ARCTIC ALASKA RIG 8 STATE ALASKA MUD COMPANY BAROID DRILLING FLUIDS SPUD DATE 1O-FEB-98 -~, BIT SIZE JETS DEPTH FEET ROP HRS TOT CST WOB RPM FLOW SSP MW GRADE REMARKS DATE TYPE NO. inches 1/32 OUT drlg ft/hr HRS $/ft klbs gpm psi ppg 0 D L B G 0 fÐW\I f\.UB) 03-1 3-98 MA-1 JSL 16.0 15-15-10D 2680 2570 102 25.2 25.2 35 1 0/25 120 680 3000 10.6 2 2 ER A E NO TD 03-22-98 2 05M 12.25 3x15-10D 5939 3259 67.6 48.2 73.4 34 20/35 155 725 2800 9.8 6 3 BT A E WT PR 03-24-98 3 MFDSSHLL 12.25 3x15-10D 6847 908 33.9 26.8 100.2 88 25/40 155 725 2850 10.2 2 3 WT A E PN BHA 03-26-98 4 MFDSSHCL 12.25 3x14-12 7034 187 20.9 9.0 109.2 350 35/40 90 720 3150 10.2 1 2 WT G E NO CP 03-27 -98 5 ARC 325C3 8.5 TFA: 1.1 7066 32 5.5 5.8 115.0 1 0/20 75 363 750 10.2 N C CP 03-28-98 RR-5 ARC 325C3 8.5 TFA:1.1 7095 29 5.0 5.8 120.8 5/10 95 365 775 10.2 2 3 CT S X NO PR 03-29-98 RR-4 MFDSSHCL 12.25 3x15-12 7476 381 31.8 12.0 132.8 150 30/40 165 725 3000 10.2 3 5 WT A3 E 1/16 NO LOG 04-05-98 6 DH70 HFN 12.25 TFA: .7778 7490 14 7.6 2.1 134.9 10/50 165 725 2900 10.2 0 0 BU X X I NO PR 04-07 -98 7 GT-CPS09D 12.25 3x16-14 8375 885 35.5 24.9 159.8 92 45 165 725 3200 10.2 6 4 BT A3 F I CD RIG 04-09-98 8 GT090 12.25 3x16-14 8860 485 26.1 18.6 178.4 144 45 170 725 3300 10.2 8 8 BC 1 +2 F 1/16 JD TQ 04-1 2-98 9 MFOSSHCR 12.25 4x16 9280 420 26.3 16.0 194.4 155 48 170 720 3350 10.2 6 6 BT M E 1/4 JD TO 04-1 6-98 10 ATJ-PS11HO 8.5 3x18 9300 20 6.9 2.9 197.3 50 75 422 950 9.6 6 7 BT A E I WT CP NO TO -. 04-17-98 11 ARC-425C3 8.5 TFA: .75 9391 91 25.0 3.6 200.9 420 11 90 367 1100 9.6 1 4 85 A X I 04-1 9-98 12 ATJ-PS11HO 8.5 3x16 9815 424 21.7 19.5 220.4 168 25 170 450 2100 9.7 6 4 CT A E 1/16 JD PTO ~ --- :- ~ =- ~ ::.,'"1 --- --- --- .- - ~ ---I .-.. --... ---I ~ ........... - CASING PROGRAM 20 inch at 110 ft ~!:>~~~~~~ LOGGING SYSTEMS 13 3/8 inch at 2664 ft A rn:ssERNJUSTIIS cotrIPÞNf 95/8 inch at 9276 ft DRILLUNG MUD RECORD inch at ft inch at ft COMPANY BP EXPLORATION - SSD FIELD/BLOCK P.B.U. EXPLORATION WELL NORTHWEST EILEEN LOCATION SEC 20 - T12N - R11 E CONTRACTOR POOL ARCTIC ALASKA STATE ALASKA MUD COMPANY BAROID DRILLING FLUIDS SPUD DATE 3-10-98 '-'. DATE DEPTH WEIGHT VIS PV yp GELS FL TR HTHP CAKE SOL OIL WATER SD CEC pH PM Pf/Mf CI- CA 1 0 secl 1998 ft Ib/gal see cp Ib/hf2 10 min 'JI1/30m Ideg F 1/32 % % % % meq/hg ppm ppm 03-10-98 110 8.7 112 12 47 26/54 11.6 2 3 0 97 0 25 9.4 .20 .20/.50 300 20 03-11-98 134 8.8 168 12 31 30/62 12.4 2 4 0 96 .3 27.5 9.8 .40 .20/.40 500 60 03-12-98 920 9.7 90 17 30 26/42 12.8 2 8 0 92 1 22.5 8.8 .15 .10/.24 280 35 03-13-98 2266 10.6 80 18 26 14/42 14.0 2 10 0 90 2 22.5 9.4 .18 .12/.25 300 52 03-14-98 2680 10.1 110 20 27 19/41 12.5 2 10.6 0 89.4 1.5 25 8.7 0 .05/.35 300 40 03-15-98 2680 10.1 44 13 6 1/2 11.0 2 10.6 0 89.4 2 22.5 8.0 0 .05/.45 300 40 03-16-98 2680 8.4 28 1 0 0/0 0 0 100 0 0 8.0 0 0/0 100 40 03-17-98 2680 8.4 28 1 0 0/0 0 100 0 0 8.0 0 0/0 100 40 03-18-98 2680 9.3 45 10 15 3/4 7.4 13.0 1 3.3 0 95 0 8.4 0 .10/.45 30000 80 03-19-98 3675 9.3 43 12 16 7/13 6.8 1 4.6 0 94 1 8.3 0 .08./48 25000 400 03-20-98 4520 9.5 45 13 26 10/19 8.0 14.5 1 5.9 .5 92 .5 7 8.2 0 .28/1.38 29000 100 03-21-98 5104 9.6 42 13 14 5112 6.2 13.6 2 6.6 .1 92 TR 15 8.2 0 1.6/1. 1 23000 72 03-22-98 5792 9.8 52 15 18 7/18 5.4 1 8.4 0 90 .25 17 8.3 0 .20/1.3 29000 80 --. 03-23-98 6112 10.0 56 17 20 9/30 7.0 14.0 2 8.4 0 90 .5 20 8.4 .4 .15/1.2 28500 112 03-24-98 6650 10.2 53 15 19 11/40 6.4 14.0 2 8.4 0 90 .25 25 8.3 0 .10/1.0 30000 80 03-25-98 6847 10.2 43 15 1113 7/26 8.6 16.4 2 8.4 0 90 .5 22.5 7.9 0 0/1.1 29000 120 03-26-98 6847 10.2 56 16 12 6/25 7.0 14.0 2 8.3 0 90 .35 25 8.0 0 .10/1.8 31000 80 03-27 -98 7034 10.2 45 14 16 3/6 4.6 11.6 1 8.1 0 90 TR 7 7.0 0 .10/.60 34000 80 03-28-98 7066 10.2 45 14 13 3/10 4.6 11.2 1 8.1 0 90 .5 12.5 8.1 0 .05/.70 34000 96 03-29-98 7095 10.2 46 14 11 3/8 5.2 11.6 1 7.2 0 91 .4 12.5 8.4 .05 .10/.55 32000 80 03-30-98 7384 10.2 54 23 28 11/27 3.6 11.0 1 9.2 0 89 .3 14 7.5 0 0/.90 34000 128 03-31-98 7476 10.2 57 19 17 7/17 3.8 10.4 1 8.5 0 89 .2 12.5 7.5 0 0/.50 28000 120 04-01-98 7476 10.2 56 20 18 8/22 3.8 10.6 1 9.3 1 88 .5 12.5 7.7 0 0/.80 32000 140 04-02-98 7476 10.2 63 23 24 9/26 3.6 8.4 1 9.3 2 87 .25 15 8.6 .25 0/1.0 32000 180 04-03-98 7476 10.2 60 21 24 10/29 3.8 1 8.4 1 89 .4 16 8.4 .15 .05/1.2 30000 100 --~ -J -. -, - --- -' ----- ~- ~ ~ ~ ~ .-.-. ,-.-.. -. -- -. I CASING PROGRAM 20 inch at 110 ft ~E~~~:-~~ LOGGING SYSTEMS 13 3/8 inch at 2664 ft A rÆSSEHNXJSTFES CONPÞNY 95/8 9276 inch at ft DRILLLING MUD RECORD inch at ft inch at ft COMPANY BP EXPLORATION - SSD FIELD/BLOCK P.B.U. EXPLORATION WELL NORTHWEST EILEEN 2-01 LOCATION SEC 20T12N R11E CONTRACTOR POOL ARCTIC ALASKA STATE ALASKA MUD COMPANY BAROID DRILLING FLUIDS SPUD DATE 3-10-98 ~~ DATE DEPTH WEIGHT VIS PV YP GELS FLTR HTHP CAKE SOL OIL WATER SO CEC pH PM Pf/Mf CI- CA 10 secl 1998 ft Ib/gal see cp Ib/hf2 10 min ml/30m Ideg F 1/32 % % % % meq/hg ppm ppm 04-04-98 7476 10.3 61 25 25 10/28 4.0 10.0 1 8.4 1 89 .5 16 8.4 0 0/1.3 30000 120 04-05-98 7489 10.2 60 21 18 11/25 3.9 9.7 1 8.3 1 89 .5 17.5 8.6 .15 .22/1.5 31000 100 04-06-98 7514 10.2 60 15 30 9/26 4.0 9.4 1 9.3 0 89 .5 20 8.4 .12 .17/1.1 31000 100 04-07 -98 8256 10.2 62 23 28 11/25 3.8 9.8 1 8.4 1 89 .3 12.5 8.7 0 0/1.2 29000 80 04-08-98 8375 10.2 67 17 26 17/32 5.1 11.1 2 8.5 2 88 .3 20 8.4 0 0/1.2 28000 180 04-09-98 8665 10.2 59 16 28 19/48 6.1 13.2 2 9.4 1 88 .3 20 8.7 .31 .20/1.8 30000 165 04-10-98 8860 10.2 65 19 32 21/43 5.6 11.6 2 9.4 1 88 .3 17.5 8.5 .05 .05/1.5 29000 80 04-11-98 9000 10.3 48 16 20 15/29 4.2 9.3 2 8.4 2 88 .3 .15 9.1 .22 .20/1.3 30000 120 04-12-98 9280 10.7 50 20 22 ~ 7/39 4.8 10.1 2 9.4 1 88 .2 20 9.1 .30 .20/1.9 29000 120 04-13-98 9280 10.7 42 13 16 101- 4.9 10.0 1 8.9 2 87.5 TR 17 8.5 0 .1/1.7 30000 120 04-14-98 9280 10.7 50 14 20 7/16 5.0 10.2 1 8.4 2 88 TR 16.5 8.8 0 .1/1.7 30000 120 04-15-98 9280 10.7 48 14 20 6/15 5.0 10.3 1 8.5 2 88 TA 16.0 8.5 0 .1/1.5 30000 100 .- 04-16-98 9280 9.6 65 21 15 3/6 3.8 8.0 1 4.3 0 94 TR 7.0 10.4 .8 .1/.9 30000 120 04-17-98 9391 9.6 54 20 14 215 3.1 8.3 1 4.8 0 93.5 .1 7.0 8.0 .8 .21.9 30000 140 04-18-98 9391 9.7 56 21 13 3/4 3.2 8.6 1 6.4 0 92 .2 12.5 8.9 1.1 .15/1.05 29000 60 04-19-98 9815 9.7 48 20 11 215 2.8 8.3 1 6.4 0 92 TR 10.0 9.0 1.1 .10/1.1 29000 80 r ( L ," { Page 1 SPERRY-SUN DRILLING SERVICES [ BP EXPLORATION (ALASKA), INC. APRIL, 1998 PRUDHOE BAY UNIT MAGUTM VALUES: I POOL 8 .DErT I TNATION::::2 7 . B 7.x NW E 2-01 DIP ANGLE=80.68x API# 50-029-22866-00 TOTAL ,FTRT.D B"rRRN~TH=572.9OnT AK-MM-80137 DATE OF MAGNETIC DATA= 3/10/98 *********************KBE=74.06' ABOVE MEAN SEA LEVEL******************** MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG DEPTH DEG DEG DEPTH FEET FEET SECTION LEG (R1\B) 1. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0..00 136.12 0.02 225.33 1.3 6 ..12. 0..02, S Q..02 W -0..Q2 0.01 243.02 0.05 250.37 243.02 0.05 S 0.07 W -0.07 0.03 339.45 0.32 93.69 339.45 0.08 S 0.15 E 0.00 0.38 427.01 0.23 82.13 427.01 0.07 S 0.57 E 0.21 0.12 520.34 0.11 99.04 52.0..34 0..06 S 0..85 E 0..35 0.14 ¡ 606.87 0.58 244.64 606.87 o . 2·6 S 0.53 E .Q . .02 0.78 696.81 0.62 240.38 696.80 0.69 S 0.30 W -0.75 0.07 788.88 0.53 .2 42 .24 788.B7 ~.14 S ~.~~ W -~..53 D..~.o 881.39 0.37 211.86 881.37 1.59 S 1.65 W -2.18 0.30 973.71 0.40 220.78 973.69 2.09 S 2.01 W -2.79 0.07 1065.82 0.38 231.86 1065.80 2.52 S 2.47 W -3.38 0.08 1162.57 0.25 228.16 liE 2 .. 55 2 . 86 S 2.B7 W -3 . B 7 0.14 1258.37 0.32 229..,8.5 1.2 58. . 15. 3. . 1.7 S 3. .23 W -4.32 0...07 1349.32 0.35 219.35 1349.30 3.55 S 3.61 W -4.83 0.07 1439.36 0.32 273.11 1439.33 3.75 S 4.03 W -5.20 0.34 1535.17 0.20 249.99 1535.14 3 . 7.9 S 4.4.5 W -5.44 0.1.6 , 1627.74 0.35 271.36 ~6.27 ..71. 3.. 84 S. 4..8,9 W -5.69. Q . 1.9 1720.35 0.32 205.37 1720..32 -4.07 S 5 . 2-8 .w -6.07 0.39 1809.03 0.36 261.20 1809.0Ç> 4.33 S 5.66 W -6.48 0.36 1994.11 0.62 296 . 69 ~.994.07 3.97 S 7.J..3 W -6.B6 o ..2~ 2087.38 0.54 286.4..7 2.0.87 ..34. 3..6.2, S 8.01 W -6.95 0...14 2180.43 0.38 273.74 21.80.39 3.~8 S 8.73 W -7.17 0.2.0 2273.84 0.32 289.74 2273.79 3.37 S 9.29 W -7.33 0.12 2366.51 0.33 299.98 2366.46 3.15 S 9.76 W -7.36 0.06 --< 2459.40 0.23 311.96 2,459.3.5 2.89 S 10.1.3 W -7.31 o . 1.2 2556.61 0.26 317.45 2556..56 2.60 S 10.43 W -7.1.9 0.-04 ~ 2632.02 0.26 333.65 2631.97 2.32 S 10.62 W -7.03 0.10 2697.65 .0.22 347.2.5 2697.60 2.06 S 10 . 7~ W -6.85 O.~~ 2790.17 1.38 41.67 2790.11 1.05 S 10.01 W -5.63 1.37 2882.37 3.49 37 .47 2882.22 2.00 N 7.57 W -1.78 2.30 2971.89 5.25 21.36 2971.48 7.98 N 4.42 W 4.97 2.38 1 3067.09 8.73 14,.2,5 306,5..96 ~.9 . 04 ,N 1. . 05 W 16.32 3.76 3160.06 9.33 1.4 . 56 31.57 . 78 3.3 . 17 N 2.58. E 30.50 0..65 3251.87 10.13 14.58 3248.27 48.19 N 6.48 E 45.60 0.87 ,:~ I ~ ¡ H I ~; ( II Page 2 r SPERRY-SUN DRILLING SERVICES BP EXPLORATION (ALASKA), INC. APRIL, ~99.a PRUDHOE BAY UNIT MAGUTM VALUES: J POOL 8 DECT,TNAT.ION;::;27.87x NW E 2-01 DIP ANGLE=80,68x API# 50-029-22866-00 TOTAL FIELD SrrRR't\IGTH=5 729DnT ( AK-MM-80137 DATE OF MAGNETIC DATA= 3/10/98 *********************KBE=74.06'ABOVE MEAN SEA LEVEL********************* MEASURED ANGLE DIRECTION VERT~CAL LATITUDE DEPARTURE VERTICAL DOG -. DEPTH DEG DEG DEPTH FEET FEET SECTION LEG (RKB) 1 3344.20 11~45 15.99 33.3B.96 64.86 N 1.1 . 05 .E 62.4.6 ~ .46 3437.12 12.89 16.40 34.2.9,79 8.3 . 67 N 16..52. E 8~. 64 1.55 ¡ 3528.32 14.66 7.07 351,8..38 10-4.89 N 20.81 E 1-02.38 3.11 3619.66 16.14 6.14 3606.43 128.98 N 23.59 E 124.97 1.64 3716.00 18.43 7.12 3698.42 157.41 N 26.91 E 151.63 2.40 .....:J 3809.47 20.45 10.11 3786.56 ~88 .15. N 31 ..6~ E 18.0..98 2.41 3902.00 22.84 1,3 . 24 3872.56 221.55 N 38.56 E 213.73 2.87 -1 3994.17 26.03 12.55 3956.46 258.71 N 47.06 E 250.53 3.47 4087.46 30.87 ~2.63 40.3B.46 3.02 . 07 .N 56.74 E 293 .37 5.~9 ( 4179.10 32.78 13.15 4116.32 349.18 N 67.53 E 340.02 2.11 4264.73 32.76 ~3 .27 41BB...32 .3.9413.0 N 7g.~2 E 384.-8-4 0..0-8 4367.89 34.23 8.24 4274.37 450.19 N 88.69 E 439.16 3.04 4455.40 35.22 5 .,6~ 4.346.. 29 4.99.. 67 .N 94.68 E 485.66 ,2.. ,0.5 455.0.72 34.98 6...~3 4,424.28. 554.19 N 10Q.29 E 536.43 0.40 4643.67 34.49 5.96 4500.66 606.86 N 105.87 E 585.56 0.54 4736.26 34.12 6.72 4577.15 658.72 N 111.63 E 634.06 0.61 4830.49 35 . ~,5 8.51 4654.68 7~J_ .80 .N 118.73.E 684.26 1.54 .J 4923.29 36.5.5. 11.01 472.9..,90 765.. 35,. N 127...97 E 735.87 2.18 5016.16 .3 7 ..9.3 ~~.79 48.03.. B4 B20 .43 N ~39.08 E 7B9.73 1.57 ,ill 5104.29 38.36 13.00 ~87~.15 873.60 N 150.77 E 842.16 0.98 1 5204.20 38.27 12.. ,8.2 495~.54 933 . 97 N .164 . 60 E 90~. .97 .0.14 5296.12 37.65 12.20 5Q24.01 989..17 N 176..8,5 E 956.46 0..79 5389.01 38.37 ~~. 78 5097..20 ~.o45.:t.2 N 188 . 74 E 1011.45 0.-82 , 5481.13 37.71 12.41 5169.75 1100.63 N 200.63 E 1066.04 0.83 5573.14 38.34 12.68 5242.23 1155~95 N 212.94 E 1120.67 0.71 5665.63 37.52 12.34 531.5.18 12.11.46 N 225...2.6 E. 1175.46 0.91 5758.84 36.89 ~3 .50 .5389.42 ,1.2 66 ..39 N 237.85 E 1229.88 1.01 5851.81 34.85 15.15 5464.76 1319.17 N 251.31 E 1282.80 2.43 5940.22 33.~~ 15.52 553B.07 .1.366.82 N 264.37 .E ~33~. O~ 1..98 6039.98 28.95 18.56 5623.54 1415.99 N 279.36 E 1381.46 4.45 6131.87 .2 6 .53 18.86 5704..86 1456.50 N 293.07 E 1423.67 2.64 6224.77 25.07 20.60 5788.50 1494.56 N 306.70 E 1463.67 1.77 6318.12 23.85 21.02 5873.47 ~530. 69 .N 3.20.4.3 .E 1502.02 1...32 ~ 6410.95 21. 95 21.99 5958.98 1564.30 N 333. . 66 E. 1537.91 2.09 6503.16 19.76 23.43 6045.15 1594.58 N 346.32 E 1570.59 2.44 I (' ( I Page 3 SPERRY-SUN DRILLING SERVICES I, BP EXPLORATION (ALASKA) , mc . APRIL , 1998 PRUDHOE BAY UNIT MAGUTM VALUES: f POOL 8 DECLINATION=27.87x NW E 2-0~ DIP ANGLE=80.68x 1 API# 50-029-22866-00 TOTAL FIELD BTRENGTB=57290nT [, AK-MM-80137 DATE OF MAGNETIC DATA= 3/10/98 *********************KBE=74.06'ABOVE MEAN SEA LEVEL********************* I. MEASURED ANGLE DIRECTION VERTICAL. LATITUDE DEPARTURE VERTICAL DOG DEPTH DEG DEG DEPTH FEET FEET SECTION LEG (RKB) 1 6596.13 17.42 25.21 6133.26 1621.60 N 358.49 E 1600.16 2.59 6688.78 17.17 29.76 62.2.~.. 72 ~646.02 N 371..1,9 E ~627.68 1..48 ..1 6781.85 ~6 .73 34.91 .6310.7.6 1668.93 N 385.68.E 1654 . 7.1 1.6.8 ~1 6-8.50.31 16-.8.7 3.9 '.0.7 6376. . 3.2 16.84.73. N 397.5.8. R 1.674..25- ~..77 6943.17 16.12 40.24 646~.33 1705..03 N 414.40 E 1700.07 0.88 -'" 7005.71 14.92 40.65 652.5..59 1717 ..76 N 425 . 2,5 E 1716.41 1.93 I, 7070.45 14.83 4~.26 6588.16 1730.3~ N 436.14 E 1732.60 0..28 7132.20 16 . 0.3. 42.78- 6647.69 174.2.51 N 447.15 E 1748.5.3 2. .05 7194.08 17.01 43.78 6707.01 1755.32 N 459.21. E 1765.51 1.65 I, 7256.16 18.09 46.84 6766.20 1768.47 N 472.53 E 1783.37 2.29 7317.97 18..9.3 5.0 . 86 6824.82 ~78.1...36 .N 487..30 E 11301.68 2.47 7409.44 20.70 58.59 6.910 .88. 1799.16 N 512.6,1. R 1829.28 1. ..45 I. 7475.00 21.58 60.85 6972.03 1811.07 N 533.03 E 1849.38 1.83 7537.73 22..81 61.19 7Q30 .11. 18,22 .55 N 553 ..76. E 186_9..,25 1...97 7600.91 23.76 61.88 7088.15 1834.45 N 575.72 E 1890.06 1.56 I. 7663.26 24.77 60.77 7144.99· 18-46,. 75 N 598-.20. E 191.1..47 1.78- 7726.73 26.18 61.09 7202.28 1860.01 N 622.06 E 1934.38 2..23 .(1 7789.20 27.84 60.84 125.7..94 ~8.73,,-78 N 646..86. E. 1,958.18 2.66 7850.83 28..05 60.3.6 7312.3B 18B 7 ...96 .N 67.2.. 02 .E 1982...5..1 O.5D 7944.71 28.21 60.06 7395.17 1909.95 N 710.43 E 2019.95 0.23 ,.J. 8037.44 2 T. 84 59.74 7477.03 1931.80 N 748.13 E, 2056.94 0.43 .('j 8130.92 27..72 59.14 755_9..74_ 1,95.3..95 N 785..65 E, 2.Q94.1.1 0..33 8224.71 27 .. 5~ 58.83 7642..84 ~.976 ..3.5 N 8.22 ...9~ E 2.131..38 0.27 8317.36 26.78 60.43 7725.29 1997.i3 N 859.37 E 2167 .36. ~.1,1 8411.91 25.46 59.62 7810.18 2018.52 N 895.43 E 22.02.65 1.45 .,J ( 8505.82 22.83 57.57 7895.87 2038.50 N 928.23 E 2235.68 2.94 8600.47 20 . 83 5.5 . 84 7.9.83 .73 2057 . 80 N ,957 .65 E 2266.54 2...22 8.693.74 1 7 . 9.4 54.78 8.071. 70 2075.40 N 98-3.12 E. 2294..03 3..12 8786.21 16.53 52.42 8160.02 2091.63 N 1005.18 E 2318.72 1.70 1 8817.97 16.39 51.93 8190.48 2097.15 N 1012.28 E 2326.93 0.62 8912.58 1.4.47 54.7.2 828~0. 67 2112.2.1 N .1032.44 234.9 .6.9 2...1.8 ,E 9006.00 10.90 58.69 8372.8.0 212.3,.55 N 10.49.52 E 2367.11 3.93 9100.34 8.58 59.88 8465.77 2131.71 N 1063.23 E 2381.36 2.47 .'J 9163.22 8.15 59.76 8527 .98 . 2136 . 31 N 1Q71.14 E 2389.13 0.68 9214.63 8.22 59.74 8578.87 2140.00 N 1077.46 E 2395.36 0.14 .". 1-\ I I I : I 1- MEASURED DEPTH r r r I I I r -J J KBE=74. 06' ABOVE MEAN SEA LEVEL SURFACE LOCATION ASP ZONE 4: . X: 570682 W Y: 5986606 N BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. TEE .BOTTOM .HOLE DISPLAC~MENT IS 2454.65 FEET, IN THE DIRECTION OF 27.75x (TRUE) TaE I>.OGLEG S.EVERITY .IS IN DEGREES PER ~OO ..00 FEET THE VERTr'êAt' 'S'ËCTION WAS' COMPUTED ALONG 27. 99x (TRUE) SURVEY PROJECTED TO TD: 9815.00 5.42 64.81 9174.64 2172.29 N 1143.01 E 2454.63 o.~o *************************************************************************** 9742.17 5.42 64.81 9102.13 2169.37 N 1136.78 E 2449.13 0.31 *************************************************************************** VERTICAL LATITUDE DEPARTURE VERTICAL DOG DEPTH FEET FEET SECTION LEG {RKB) 8678.0.0 214-6.92 N 1090.44 E 2407.56 0.77 8772.72 2153.09 N 1103.05 E 2418.92 0.50 8865.7~ 2~5,8.56 N . 1114..22 .E .2428 .99 ~..23 8.959.6a 2.1,6,3 .. 32. N 1123 ..,92. E 2,437 .,75 1..Q2 9054.62 2167.46 N 1132.64 E 2445.50 0.61 9314.85 9410.60 9504.42 9.59.9 .. O~. 9694.44 64.00 63.87 63.97 63.67 65.71 8,.67 8.19 7.04 6.08 5.54 DIRECTION DEG ANGLE DEG *********************KBE=74.06' ABOVE MEAN SEA LEVEL******************** APJUL # ..19.9.B MAGUTM VALUES: DECLINATION:27.87x DIP ANGLE=80.68x TOTAL FIELD .sTRENGTH=-57290nT DATE OF MAGNETIC DATA= 3/10/98 INC. BP EXPLORATION (ALASKA), PRUDHOE BAY UNIT POOL 8 NW E 2-01 API# 50-029-22866-00 AK-MM-80137 SPERRY-SUN DRILLING SERVICES Page -4 ( (' I I " I I I I II I ¡ II 1 "1 ...J ~ I I I J ( ( SHOW REPORTS This section of the report contains copies of show evaluation reports for NWE 2-01. These reports are based, on chromatograph evaluations of gases retrieved from mud samples injected into Sperry-Sun's Steam Still apparatus; consequently, interpretations made on each report reflect this procedure. The fIrst three of the show reports in this report did not use a steam still apparatus to extract the gas for analysis and are so noted on the reports. Show reports are not always included in the well report analysis because of restricted infonnation requirements placed on some wildcat wells. They do offer some insight of fluid content on potential producing zones of good permeability; however, they are often inadequate on tight zones or when mud-gas samples are taken while coring. See attachment regarding SPE-AIME, B.O. Pixler referencing hydrocarbon ratio evaluations. -I ,¡ 1 _J I .J I I I J I j I ~ I .,' 1 ( I ~~~~~=~~~ LOGGING SYSTEMS A Œ£SSER N)l/$1ŒS COfIPW( I Operator BP EXPLORATION . Well Name NORTHWEST EILEEN 2-01 J Location PRUDHOE BAY UNIT t ( . 1 3660 ft 0 % ...J -.:J DEPTH . GAS ŒJ units 1475 MUD CHLORIDES (ppm) 25000 ----RÕWlmÈ----šüëriõÑ-~---ŠHÕW-------------------------- ,'.'1 ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS ;....:J C 1 17,400 = 17,400 C 1 I C 2 = 20 I C 2 aao = aao C 1 / C 3 = 155 C 3 112 = 112 · C 4 64 = 64 C 1 IC 4 = 'Z72 I : p\~~~i-¡;lfÑ - O~;$- -0~~L- :=0;; ;:~ - -êf Ñ~Ñ_;Ã~t~c~5ãLi ~ŸD~;!!:~BÕÑŠ - · ~ DEPTH 3695 ft. GAS DF)(! % . 1500 MUD CHLORIDES (ppm) 25000 "I ~ Units ----Rõwi~E----SÜCTIÕÑ-~---ŠHÕW-------------------------- ;;¡ ppm - ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS , C 1 1 5.200 = 1 5.200 C 1 / C 2 = 25 C2 ~o = ~o . C 3 C 1 / c 3 = 133 114 = 114 C 4 96 = 96 C 1 / c 4 = 158 C 5 15 = 15 C 1 IC 5 = 1,013 . ------------------------------------------------------- P'l~~~~¡:~N DGAS mOIL DWATER 0 NON-PRODUCIBLE HYDROCARBONS , ' LfTHOLOGY ,::d SAND- CLEAR TO OPAQUE, WHITE, MEDIUM GREY, BLACK. FINE TO COARSE GRAINED, ANGULAR TO SUB ROUNDED, POORLY SORTED, UNCONSOLIDATED TP OCCASIONALLY CEMENTED WITH ,--t CALCAREOUS CLAV, 70% QUARTS - 30% CHERT + LITHIC FRAGMENTS, TRACE PVRITE. 2DNE PRODUCTION CONTACT DEPTH ( Show Report Part B Depth Interval 3620 to 3700 True Vert.Depth 3606 to 3680 Prepared by J. PATTON Delivered to TOM SIMONS Date 3/19/98 Time DGAS D WATER IX] NON-PFVDUCIBLE HYDROCARBONS [X] OIL Gas/Water ---------------------------------------------------------------------------. ft. Gas/Oil ft. SHOW EVALUATION FREE OIL IN SAMPLES AND MUD, FAINT OIL ODOR. LIGHT PALE ORANGE FLUORESCENCE. LIGHT BROWN VISUAL CUT. VERV GOOD MILKY PALE GOLD - WHITE CUT FLUORESCENCE. "d FAIR-GOOD HEAVY OIL SHOW IN THE UGNU. REMARKS E GAS ANAL VSIS DONE FROM TRAP LINE - NO STEAM STILLS ON THIS SAMPLE. ZONE APPEARS TO CONTAIN HEAVY OIL AND LACKS GOOD C3-C5 READINGS FOR STEAM STILL ANAL VSIS. GOOD RESISTIVITY AND BACKGROUND GAS READINGS. ft. Oil/Water ffi) 41) 3D aD HYDROCARBON RATIOS ..£.t.. ..£.t.. ..£1.. ..£.t. c? c3 c4 c5 NONfXtOOIJC-IVF 1m m 6) ~ 4) 3) ðA3 2) + f./A 10 a 6 4 3 ulL 2 ffi) 4D 3D HVDROCARBON RATIOS ..£.L ..£.L ..£.t. ..£.L c;> c3 c4 c5 aD NONP100UCTIVF 1m / ffi ./' 6) , 4J 3) GAS 2) Jf N,Á- 10 a 6 ull 4 3 2 ( :' ~~~~~=~~~ LOGGING SYSTEMS ~ A £F£S$ER NXJSlRES CONPMN -~ Jperator BP EXPLORATION , Nell Name NORTHWEST EILEEN 2-01 , Location PRUDHOE BAY UNIT t -' 2DNE PRODUCTION CONTACT DEPTH ( Show Report 2 Part B Depth Interval 4070 to 4140 True Vert.Depth 4022 to 4083 Prepared by J. PATTON Delivered to TOM SIMONS Date 3/19/98 Time D WATER D NQttHJR)[)lJCIBLE HYDROCARBONS [X] OIL DGAS ft. Gas/Water ---------------------------------------------------------------------------- ft. Oil/Water ft. Gas/Oil ~. 5 I 4080 ft 0 % ...:.J DEPTH . GAS ŒJ units 3500 MUD CHLORIDES (ppm) 25000 ----~õwirnÈ----šüëriõÑ-~---ŠHÒW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS ,~- C 1 318,000 ¥ = 318,000 C 1 I C 2 = 30 C 2 10,500 = 10,500 122 C 1 IC 3 = C 3 2.600 = 2.600 C 4 2,860 = 2,860 C 1 IC 4 = 111 . ¡ C 5 1 ,11 5 = 1 ,11 5 C 1 I C 5 = 285 - p~ï~~~~1~Ñ - [j~;; -[~fO~L- - [j~; ;E~ - -Ö- ~~~-~~~~~C-I~L-E -~Y""o-RõëÃÃBÕÑ$ - '. 61 ft 0% . ~ DEPTH 4110 . GAS I'X1 't ~ ums ------------------------------------------------------- FLOWLINE SUCTION _ SHOW ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS ,";' C 1 390,000 k = 390.000 C 1 I C 2 = 27 C 2 1 4,200 = 1 4,200 115 C 1 IC 3 = C 3 3,380 = 3,380 C C /c = 102 4 3,840 = 3,840 1 4 C 5 1,700 = 1 .700 C 1 / C 5 = 229 j - p~~~ï~¡lgÑ - D~¡s- -m~~L- - [j;~;i"R- -ëf ~~~-~~~~~C~~lE-HYDÃõëÃR-BÕÑ$- t UTHOLOGY :'/ J SAND-MEDIUM GREY, BROWN, CLEAR TO OPAQUE, BLACK, FINE TO MEDIUM GRAINED, COARSE GRAINED IN PART, ANGULAR TO SUB ROUNDED, MODERATELY SORTED UNCONSOLIDATED 70% QUARTZ- 30% CHERT + LITH, OCCASIONAL CARBONACEOUS FRAGMENTS. 3380 MUD CHLORIDES (ppm) .A ,j' SHOW EVALUATION OIL STAIN IN PART, FREE OIL IN MUD, FAINT OIL ODOR. 70% DULL YELLOW-WHITE FLUORESCENCE IN SAMPLE, PALE YELLOW -WHITE MILKY GOLD CUT FLUORESCENCE. , GOOD MODERATELY HEAVY OIL SHOW IN THE WEST SAK - SCHRADER BLUFF. REMARKS , -~ GAS ANALYSIS DONE FROM TRAP LINE - NOT A STEAM STILL SAMPLE. ZONE APPEARS TO CONTAIN MODERATELY HEAVY OIL AND WITH GOOD AUTO SAMPLE C3-C5 READINGS. HIGH BACKGROUND GAS AND GOOD RESISTIVITY READINGS. HYDROCARBON RATIOS ...£l- ...£l- ..£L ..£L 5D Cj) C3 C4 Cs 4D 3D :aD NONpq()IlIJC11VF 1m ./ ID / to 4J 3) QA8 2) ~NA: 10 8 6 OIL 4 3 2 HYDROCARBON RATIOS ..£L ..£L ...£:L ..£L 5D C;> C3 C4 C5 4D 3D :aD NON~DUCTIVE 1m ./'/ ID to ,. 4J 3) ~ 2) ~ NA: 10 8 6 OIL 4 3 2 ( Show Report 3 Part 8 Depth Interval 4215 to 4255 True Vert. Depth 4147 to 4181 Prepared by J. PATTON Delivered to TOM SIMONS Date 3/19/98 Time "I .1 ~. I ~~~~~=~~~ LOGGING SYSTEMS . A ŒESSER N)lJS1FES COWl'ÞNf 1 Operator BP EXPLORATION Well Name NORTHWFST Ell FFN ~-01 . Location PRUDHOE BAY UNIT l l 1 ~ DEPTH 2DNE PFÐDUCTlON CONTACT DEPTH [X] Oil D WATER D NON-PR)()lJCIBLE HYDROCARBONS DGAS Gas/Oil ft. Gas/Water ---------------------------------------------------------------------------~ Oil/Water ft. -t,,? I~/" .,"n """ ^nlnr~ 1___\ ...ennn I IYIVU \lnLVnIUI:.~ UJJ1II1 o!:.;)UUU ft 0% "'A~ . '" f'\~ Mx . ~ umts 4240 ----RÕWLWÈ----SÜCTIÕÑ-~---ŠHÕW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARaON RATIOS ->I e 1 1 85, 000 ~ = 185,000 C 1 I C 2 = 32 c 2 5,800 = 5,800 e 3 e 1 /c 3 = 1,555 119 = 119 I e 4 204 = 204 C 1 / e 4 = 907 .' e 5 324 = 324 C 1 I C 5 = 571 - PÃA%~~~~1iÑ - [j~;s- - 0~~L- - D~;;E~- -Ö- ~~Ñ-p~~~~e~~L-E-HY-D-R~ëÃÃB~~~- ~ DEPTH 4110 ft. GAS ~x % .t 3380 MUD CHLORIDES (ppm) ~ ums ----RÕWLrnË----$ÜëriõÑ-~---ŠHÕW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS I e 1 136, 000 ~ = 136,000 e 1 / e 2 = 36 C 2 3,800 = 3,800 e 1 Ie 3 = 1,971 e 3 69 = 69 e 4 109 = 109 e 1 Ie 4 = 1,248 C 5 190 = 190 C 1 /C 5 = 716 ~' - P~~~~~¡ï~Ñ - [j~;s- - Œ:i~~L- -[j;~;E~- -Õ- ~~Ñ-P~~~~C~~L-E-H'¡D~~~ÃÃBÕ~~- , UTHOlOGY i~ -. SAND-CLEAR TO OPAQUE, GRAY, CREAM, BLACK, FINE TO MEDIUM GRAIN, COARSE GRAIN IN PART, ANGULAR TO SUBANGULAR, WELL. SORTED, UNCONSOLIDATED, LITHIC IN PART, 80% QUARTZ, 20% LlTHICS, CLEAN, CARBONACEOUS IN PART, NONCALCAREOUS. .,. J J SHOWEVALUAll0N 30% YELLOW FLUORESCENCE, VERY LIGHT TAN WHITE LIGHT CUT, ]( GOOD WHITE TO PALE GOLD CUT FLUORESCENCE. II FAIR MODERATELY HEAVY OIL SHOW IN THE WEST SAK-SCHRADER BLUFF. REMARKS r· ~GAS ANALYSIS DONE FROM TRAP LINE - NOT A STEAM STILL SAMPLE. ZONE APPEARS TIGHT AND CONTAINS MODERATELY HEAVY OIL. GOOD AUTO SAMPLE C3-C5 READINGS. GOOD BACKGROUND GAS I AND GOOD RESISTIVITY READINGS. j ft. ~ <II) 3D HYDROCARBON RATIOS ..£1.. ..£1.. ..£..t. ..s.. C2 C~ C4 Cß 2D NONpqoOI JCTlVF 1m ID 6) ~ -' .() 3) 2) BAS Jf II It. 10 8 6 4 3 Oil 2 ffi) .m 3D :m HYDROCARBON RATIOS ..s. ..s. ..£..t. ~ c:; c3 c4 c5 NONP1ODUCTlVE 1m 8) ff) /' ~ .;' .I() 3) GAS 2) "¥ /Ý 4- 10 8 6 ull 4 3 2 ~~ ~( r ~~~!~::.~~_~ LOGGING SYSTEIIS A Œ£SSER NJUSTFES COM'ÞNf ,Operator BP EXPLORATION Nell Name NORTHWEST EILEEN 2-01 . Location PRUDHOE BAY UNIT 2DNE PRODUCTION CONTACT DEPTH [X] OIL D WAlER [X] NON-PR>DUCIBLE HYDROCARBONS DGAS ( Sho'h t.~po rt 4 Part B Depth Interval 7043 to 7061 True Vert. Depth 6560 to 6577 Prepared by J. PATTON Delivered to TOM SIMONS Date 3/27/98 Time ft. Gas/Water ---------------------------------------------------------------------------- Oil/Water Gas/Oil - ~ DEPTH 7046 ft. GAS ~x %, ~ umts ------------------------------------------------------- FLOWLINE SUCTION _ SHOW ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 17,200 132 = 17,068 C 1 / C 2 = 11 C 2 1 ,640 34 = 1 ,606 C 1 /C 3 = C 3 1 ,1 30 50 = 1 .080 C 4 1 ,360 1 26 = 1 .234 C 1 / C 4 = 14 C 5 1,272 216 = 1,056 C 1 /C 5 = 16 - p~ï~~?~1~Ñ - [j~¡s- -ŒiO~L- - D;~;E~- -ŒJ- Ñ~~-~Ã~~~¿I~L-E- ~;D-RÕëÃÃBÕÑ$- '- ~ DEPTH 7053 ft. GAS DfX1 % 't 208 MUD CHLORIDES (ppm) 34000 ~ ums ,..-< - - - -F-lÕWL.I-NË- - - - šuc-TïõN- - -=-- - - SHÕW- - - - - - - - - - - - - - - - - - - - - - - - -- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 26.200 132 = 26,068 C 1 / C 2 = 11 C 2 2,340 34 = 2,306 C 1 /C 3 = 17 ~ c 3 1,590 50 = 1,540 C 4 1 ,920 1 26 = 1 ,794 C 1 I C 4 = 15 I : C 5 1 ,759 21 6 = 1 .543 C 1 I C 5 = 17 l' - P~~~~$~I~Ñ - [j~;S- -OO~~l- - [j;~;E~- -Œf Ñ~~-~Ã~~~¿;~l-E-~ŸD"RõëÃÃB~Ñ$- .., UTHOLOGY :.~ SAND-CLEAR, OPAQUE IN PART, TAN, BROWN IN PART. FINE TO MEDIUM GRAIN, ANGULAR TO SUBANGULAR, SUBROUNDED IN PART, UNCONSOLIDATED IN SAMPLE, QUARTZ, PYRITE, CARBONACEOUS. MATERIAL IN PART. 173 MUD CHLORIDES (ppm) 34000 16 SHOW EVALUATION r TRACE OF BROWN STAIN ON QUARTZ GRAINS, 25% SPOTTY DULL TO BRIGHT YELLOW SAMPLE FLUORESCENCE, POOR YELLOW TO WHITE LEACH CUT FLUORESCENCE, TRACE DARK GRAY RING WHITE LIGHT CUT. POOR-FAIR MEDIUM GRAVITY OIL SHOW IN THE KUPARUK - C INTERVAL. ZONE APPEARS TIGHT. _ REMARKS , GAS ANALYSIS FROM STEAM STILL. RATIO ANALYSIS OF C 1-C5 , READINGS INDICATE OIL IN THIS ZONE. POOR GAS AND CUTTINGS SAMPLES WHILE CORING MAKE DEFINITIVE EVALUATION DIFFICULT. WILL LATER MODIFY ANALYSIS WITH MWD RESISTIVITY READINGS. ft. ft. 9D <II) 3:D HYDROCARBON RATIOS ..s.. ..s.. ...£l. ..s.. C;> C3 C4 C5 :a:D NONP-1OIlJ JCllVF 1m ID m / 4} 3) æ QA3 10 8 6 4 3 ull 2 HYDROCARBON RATIOS ..s.. ..£.L ...£.L ..£L 9D c;> c3 c4 c5 .m 3:D :a:D NONP =DDUCTlVE 1m ,,/ ID ~ ID ,. 4} 3) GAS æ 10 "./ 8 6 ulL 4 3 2 I ,I l I ~~~~~:-~~-~ LOGGING SYSTEMS . A Œ£SSER f\DJ$1ÆS CONPANf 1 Operator BP EXPLORATION Well Name NORTHWEST EILEEN 2-01 · Location PRUDHOE BAY UNIT l I I 2DNE PRODUCTION CONTACT DEPTH [X] OIL DGAS D WAlER [X] NON-POODUCIBLE HYDROCARBONS ;( Show Report 5 Part B Depth Interval 7070 to 7087 True Vert.Depth 6586 to 6602 Prepared by J. PATTON Delivered to TOM SIMONS Date 3/28/98 Time Gas/Water ---------------------------------------------------------------------------- ft. Gas/Oil ft. 5 I 7073 ft 0 % ,..1 ~ DEPTH . GAS Œ] units 175 MUD CHLORIDES (ppm) 34000 ------------------------------------------------------- FLOWLINE SUCTION _ SHOW ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS ..... C 1 30,200 132 = 30,068 C 1 I C 2 = 12 (', C 2 2,440 34 = 2,406 22 C 1 IC 3 = C 3 1 ,440 50 = 1 ,390 C 4 1 ,51 0 1 26 = 1 ,384 C 1 / C 4 = 22 C S 1 ,315 21 6 = 1 ,099 C 1 Ie 5 = 27 - P~~~~~~gÑ - D~;s- -ŒJ-o~l- - D;~;E~- -ŒJ- ~~Ñ~~~~~C-,Bl~- ~ŸD-RÕëÃÃBÕÑ$- d ~ DEPTH 7080 ft. GAS DJX1 % 't 233 MUD CHLORIDES (ppm) 34000 , ~ ums ~ ----Rõwi~E----šüëTIõÑ-~---SHÕW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 1 2,300 1 32 = 1 2,1 68 C 1 I C 2 = 1 0 C 2 1 .21 0 34 = 1 ,176 C , IC 3 = 15 C 3 870 50 = 820 C 4 1,131 126 = 1,005 C 1 IC 4 = 12 ! C 5 1,221 216 = , ,005 C 1 IC 5 = 12 - PÃA~~~~~1~Ñ - [j~¡s- -ŒJ~~l- - [j~~;E~ - -Œf ~~Ñ-~~~~~C~;l-E- ..ïŸo""Rõë;ÃBÕÑŠ- .~ lITHOLOGY SAND- CLEAR, OPAQUE IN PART. BROWN IN PART, FINE TO MEDIUM GRAIN, ANGULAR TO SUBANGULAR, UNCONSOLIDATED IN SAMPLE, CONSOLIDATED IN PART, TRACE SILICEOUS CEMENT, QUARTZ, . TRACE GLAUCONITE, CARBONACEOUS MATERIAL CEMENT IN PART, TRACE TO 5 % VISUAL POROSITY IN CONSOLIDATED FRAGMENTS. SHOW EVALUATION MODERATE AMOUNTS OF BROWN STAIN ON QUARTZ GRAINS, 20% DULL TO BRIGHT YELLOW SAMPLE FLUORESCENCE, POOR TO FAIR VERY SLOW BRIGHT YELLOW TO WHITE STREAMING CUT FLUORES- CENCE, TRACE GRAY WHITE LIGHT CUT. POOR-FAIR MEDIUM GRAVITY OIL SHOW IN THE KUPARUK - C , INTERVAL. ZONE APPEARS TIGHT. .;'} REMARKS d GAS ANALYSIS FROM STEAM STILL. RATIO ANALYSIS OF C1-C5 P READINGS INDICATE OIL IN THIS ZONE. POOR GAS AND CUTIINGS SAMPLES WHILE CORING MAKE DEFINITIVE EVALUATION DIFFICULT. j WILL LATER MODIFY ANALYSIS WITH MWD RESISTIVI1Y READINGS. ~. ,:t ft. Oil/Water ffi) 4D 3D HYDROCARBON RATIOS ..£.J.. . ~ ...£l. ~ C;> C3 C4 Cs ID1 NONpqnnUCTlvr= 1m ID ID -,/ ~ 4) 3) CAS / 3) 10 8 6 4 3 2 ulL 1 ' ffi) 4D aD ID1 HYDROCARBON RATIOS ~ ~ ..£.t. ..£.L c;> c3 c4 Cs NONI^VDUCtIVE 1m ID ID ~ ~' ~ 4) 3) 3) GAS 10 8· 6 ùlL 4 3 2 ;~I (' ... I ~~~~~:-~~-~ LOGGING SYSTEMS J A [J£SSER N)lJSlÆS COfJPÞH( 1 Operator BP EXPLORATION Well Name NORTHWEST EILEEN 2-01 J Location PRUDHOE BAY UNIT I J i I 2DNE PFDDUCTlON CONTACT DEPTH :(, Show Report 6 Part B Depth Interval 7128 to 7173 True Vert.Depth 6636 to 6679 Prepared by J. PATTON Delivered to TOM SIMONS Date 3/29/98 Ti m e DGAS DOlL D WAlER [i] NON-POODUCIBLE HYDROCARBONS Gas/Oil ft. Gas/Water ---------------------------------------------------------------------------- ft. Oil/Water ft. 5 I 7135 ft 0 % ~J ~ DEPTH . GAS ŒJ units 637 MUD CHLORIDES (ppm) 32000 ------------------------------------------------------- FLOWLINE SUCTION _ SHOW ." ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS .....J C 1 34,200 132 = 34,068 C 1 / C 2 = 16 C 2 2,220 34 = 2,1 86 I C 1 /C 3 = 23 C 3 1 ,540 50 = 1 .490 'I C 4 1,640 126 = 1.514 C 1 /C 4 = 23 C 5 1 ,401 21 6 = 1 ,1 85 C 1 / C 5 = 29 I, - PÏ}.ï~~~11gÑ - OO~;s- - c:fo ~L- - D;; ;E~ - - ŒI- ÑÕÑ.~ÃÕ~~c""I;L-E - ";-;D ÃÕêÃÃBÕÑã - ~ DEPTH 7170 ft. GAS ~x % "t 548 MUD CHLORIDES (ppm) 32000 l ~ unl s , ----~~~J~Ë----šü~~õÑ-~--~~~w-------------------------- (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 29,800 1 32 = 29.668 C 1 / C 2 = 16 C 2 1.870 34 = 1,836 C 1 /C 3 = 23 C 3 1 ,350 50 = 1 ,300 C 4 1,500 126 = 1,374 C 1 /C 4 = 22 C 5 1,352 216 = 1,136 C 1 / C 5 = 26 il · - P~~~~~~ïgÑ - Œ1~¡s- -Ö-O~L- -ti~~;E~- -i!f ~~Ñ.~~~~~~~L-E-H'¡D-RÕëÃR-BÕÑ$- UTHOLOGY SAND/SANDSTONE- CLEAR, LIGHT TO MEDIUM BROWN, GRAY, VERY FINE TO MEDIUM GRAIN, TRACE COARSE GRAIN, SUBANGULAR TO SUBROUND, ROUND IN PART, POORLY SORTED, UNCONSOLIDATED IN SAMPLE, CONSOLIDATED IN PART-CEMENTED WITH SILICA AND BROWN SILTSTONE, 70% QUARTZ, 30% BROWN SILTSTONE LlTHICS. CARBONACEOUS, TRACE PYRITE, VERY SLIGHTLY CALCAREOUS. SHOW EVALUATION 5% VISUAL POROSITY IN CONSOLIDATED SANDSTONE FRAGMENTS, MODERATE TO ABUNDANT BROWN STAIN IN VERY FINE GRAIN SAND- STONE FRAGMENTS AND ON QUARTZ GRAINS, FAINT OIL ODOR, 40% DULL TO BRIGHT YELLOW SAMPLE FLUORESCENCE. " -.' I POOR GAS SHOW WITH RESIDUAL OIL IN THE KUPARUK - B. .f REMARKS GAS ANALYSIS FROM STEAM STILL RATIO ANALYSIS OF C1-C5. READINGS INDICATE GAS IN THIS ZONE. MODERATE GAS READINGS AND FAIR SAMPLES. MWD RESISTIVITY READINGS OF 4-6 OHM-M THROUGH INTERVAL INDICATING WATER SATURATION OR POOR POROSITY. ~" !m <II) 3D aD HYDROCARBON RATIOS ..£l.. ..£l.. ...£.t. ..£l.. C:;> C3 C4 Cs NON~nlJC-'VF 1m m m 4) 3J ~ 3) / 10 8 6 ulL 4 3 2 ~ !m <II) 3D HYDROCARBON RATIOS -£t. ..£l.. ...£.t. ...£J.. c:;> c3 c4 Cs aD NONpqQDlJCllVF 1m m m ../ , 4) 3) ~ / 3) 10 8 6 4 3 2 ulL I, ( (.,' ~~~~~=~~E~ LOGGING SYSTEIIS A D£SSER N)lJ$1fES CONPÞNf Operator BP EXPLORATION I Well Name NORTHWEST EILEEN 2-01 · Location PRUDHOE BAY UNIT [ 2DNE PRODUCTION CONTACT DEPTH DOll DGAS [XJ WAlER [XJ NON-PFDDUCIBLE HYDROCARBONS (0 Show neport 7 Part B Depth Interval 7237 to 7280 True Vert.Depth 6751 to 6791 Prepared by J. PATTON Delivered to TOM SIMONS Date 3/30/98 Time Gas/Water ---------------------------------------------------------------------------- ft. Oil/Water ft. r I Gas/Oil ft. ~ 7260 ft D% _~ DEPTH . GAS ŒJ units 440 MUD CHLORIDES (ppm) 32000 ----~õwi~È----šuëTIÕÑ-~---ŠHÕW-------------------------- ppm - ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS ..... C 1 21 ,200 1 32 = 21 ,068 C 1 / C 2 = 17 c 2 1,290 34 = 1,256 21 C 1 IC 3 = C 3 1.050 50 = 1,000 C 4 1 .265 1 26 = 1 ,1 39 C 1 Ie 4 = 18 C 5 1 ,184 216 = 968 C 1 I C 5 = 22 - P~~~~~~1~Ñ - Œï~;s- -Õ~~L- -0~~;E~- -c:f ~~~-~~~~~C~~L-E-~Y-D-R~ëÃR-BÕÑ;- · ~ DEPTH 7270 ft. GAS DIX1 % "t 455 MUD CHLORIDES (ppm) 32000 ~ ums ----~õwi~Ë----šüëTIõÑ-~---ŠHÕW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 27,600 132 = 27,468 C 1 I C 2 = 18 C 2 1,550 34 = 1,516 C 1 IC 3 = 23 L C 3 1 ,230 50 = 1,1 80 C 4 1,480 126 = 1,354 C 1 I C 4 = 20 } C 5 1 .471 21 6 = 1 ,255 C 1 I C 5 = 22 ~ - pÃA~~ï~~~Ñ - f8j~¡s- DO~L- - Œj~~;E~-,-[f ~~~-~~~~~~~lË-H;D-R~ëÃR-BÕÑ;- 1 lITHOLOGY .~ .,' l SAND/SANDSTONE- CLEAR, LIGHT BROWN, VERY FINE TO MEDIUM GRAIN, TRACE COARSE GRAIN, SUBANGULAR TO SUBROUND, POORLY SORTED, UNCONSOLIDATED IN SAMPLE, TRACE FRIABLE LIGHT BROWN SANDSTONE. _'t.- I SI-IO'tIV EVALUATION TRACE DULL YELLOW FLUORESCENCE, BROWN STAIN, SLIGHT YELLOW TO WHITE STREAMING RESIDUAL CUT FLUORESCENCE. ~' . . J POOR GAS SHOW WITH TRACE RESIDUAL OIL IN THE KUPARUK - A. REMARKS GAS ANALYSIS FROM STEAM STILL RATIO ANALYSIS OF C1-C5 II READINGS INDICATE GAS IN THIS ZONE. MODERATE GAS READINGS : AND FAIR SAMPLES. MWD RESISTIVITY READINGS OF 2-4 OHM-M THROUGH INTERVAL ~ INDICATING WATER SATURATION, ffD 4D an HYDROCARBON RATIOS .s.. .s.. ~ .s.. C/ C3 C4 C5 :m NONfKDDUCIVF ./ 1m w m 4) 3) QA3 æ --- ~ ~ 10 8, 6 OIL 4 3 2 ffD 4D an HYDROCARBON RATIOS .s.. .s.. .s. .s.. C/ C3 C4 C5 :m NONpqnnUCllVF 1m w m ./' ., 4) 3) aA3 æ ". ~ 10 8 6 4 3 ull 2 [ ( - ~.e.~~~=~~~ LOGGING SYSTEIIS A m:ssER NJUS1ÆS CONPANY ~ Operator BP EXPLORATION Well Name NORTHWEST EILEEN 2-01 . Location PRUDHOE BAY UNIT 2DNE PRODUCTION CONTACT DEPTH ,(" Show Report 8A Part B Depth Interval 9338 to 9374 True Vert. Depth 8700 to 8736 Prepared by J. PATTON Delivered to HARRY HAYWOOD Date 4/17/98 Time DGAS [K] Oil D WAlER D NON-PfÐDlJCIBLE HYDROCARBONS Gas/Oil ft. Gas/Water ---------------------------------------------------------------------------- 51 9340 ft D% -.::J DEPTH . GAS ŒJ units 377 MUD CHLORIDES (ppm) 30000 ----~ÕWi~È----ŠUCTIÕÑ-~---ŠHÒW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000'5) HYDROCARBON RATIOS - C 1 18,200 1,670 = 16,530 C 1 IC 2 = 12 r C 2 1.510 103 = 1.407 C 1 IC 3 = 14 C 3 1 ,300 82 = 1 ,21 8 r C 4 1 .394 84 = 1 .31 0 C 1 / C 4 = 13 I C 5 1.210 83 = 1,127 C 1 IC 5 = 15 - p~ï~ï~~1~Ñ - tï~;; -ŒJ-O~L- - D~~;E~- -ëf ~~~-;~~~~~~L-E-~;D-RÕë;ÃB~ÑS- ~ DEPTH 9350 ft. GAS gx % "t 1414 MUD CHLORIDES (ppm) 30000 ~ ums ----FLÕwi~Ë----SUCTIÕÑ-~---SHÕW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 34,600 1 ,670 = 32,930 C 1 I C 2 = 10 C 2 3,260 103 = 3,157 11 C 1 /C 3 = C 3 3,060 82 = 2,978 C 4 4,155 84 = 4,071 C 1 I C 4 = 8 C 5 4,428 83 = 4,345 C 1 /C 5 = 8 . "~ - p~ï~ï~~lgÑ - [j~¡s- -ŒJ~~L- - [j ~~;E~ - -Õ- ~~~-;~~~~ë;~L-E- HYD-RÕë;R-BÕÑS - UfHOLOOY SAND/SANDSTONE-TRANSLUCENT. LIGHT GRAY, CLEAR. VERY FINE TO FINE GRAIN, ROUND TO SUBANGULAR, MODERATELY WELL SORTED, UNCONSOLIDATED QUARTZ.. SHOW EVALUATION POOR PALE AND DULL YELLOW - WHITE FLUORESCENCE ( FROM 9340 AND 9350 CUTTINGS SAMPLES), SLOW YELLOW - WHITE HALO CUT FLURESCENCE FROM DRY CUTTINGS, FLUORESCENCE FADES WITH TIME EXPOSURE TO AIR. GOOD SHOW FOR VERY LIGHT GRAVITY OIL / CONDENSATE IN SAG R. - REMARKS GAS ANALYSIS FROM STEAM STILL RATIO ANALYSIS OF C1-C5 READINGS INDICATE OIL IN THIS ZONE. GOOD GAS READINGS AND FAIR SAMPLE QUALITY. MWD RESISTIVITY READINGS RELATIVELY LOW 4-8 OHM-M. ft. Oil/Water ft. HYDROCARBON RATIOS ..£1. ..£1. ...£.1. ..£1. ffD C.7 C3 C4 c5 <II) 3D 2D NONpcrJnl JCìVF ~ 1m ~ ID m ,.. 4) 3) aAS 2) 10 8 6 ull 4 3 2 ffD <II) 3D 2D HYDROCARBON RATIOS ..£1. ..£1. ...£.1. ..£..t. c:; c3 c4 c5 NONfK¥)OUC1NF 1m ID m ~ 4) 3) 2) QA3 10 8 6 ull 4 3 2 1 (' .... l ~~~~~=~I~_~ LOGGING SYSTEMS A LÆSSER tÐ.JS1FES COWPÞNY "(,operator BP EXPLORATION , Well Name NORTHWEST EILEEN 2-01 · Location PRUDHOE BAY UNIT 1 ZONE PRODUCTION CONTACT DEPTH [XJ OIL DGAS D WAlER D NON-PRODUCIBLE HYDROCARBONS ¡(' Show Report 8 B Part B Depth Interval 9338 to 9374 True Vert. Depth 8700 to 8736 Prepared by J. PATTON Delivered to HARRY HAYWOOD Date 4/17/98 Time ft. Gas/Water ---------------------------------------------------------------------------. ft. Oil/Water ft. Gas/Oil 5 I 9360 ft D % ~i ...::J DEPTH . GAS ŒJ units 1916 MUD CHLORIDES (ppm) 30000 ----~ÕWlmÈ----ŠÜCTIÕÑ-~---ŠHÕW-------------------------- ppm - ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS .;.;f C 1 36.200 2,120 = 34,080 C 1 / C 2 = 9 C 2 3,860 232 = 3,628 ( C 1 /C 3 = 9 C 3 4,050 258 = 3,792 . e 4 5,750 369 = 5.381 e 1 Ie 4 = 6 C 5 6,151 500 = 5,651 C 1 IC 5 = 6 ( - p~ï~~~¡ï~Ñ - [j~;$- - Œf~ ~L- - [j; ~;E ~ - -Õ- ~~~.pÃ~Õ~e~BL-E - ";-;DÄõëÄÃBÕÑS - ~ DEPTH 9370 ft. GAS D'Xl % .t 542 MUD CHLORIDES (ppm) 30000 ~ ums ----RÒWLWE----süëñõÑ-::--ŠHÕW-------------------------- ppm - ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 1 6,1 00 2.120 = 1 3,980 C 1 I C 2 = 11 C 2 1 ,500 232 = 1 ,268 12 ¡ C 1 /C 3 = C 3 1,380 258 = 1 ,1 22 C 4 1.668 369 = 1 ,299 C 1 / C 4 = 11 C 5 1 ,763 500 _ = 1 ,263 C 1 / C 5 = 11 ,- - p~mï~~ï~Ñ - D~¡s- -ŒJ~~L- - [jW~;E~ - -Ö- ~~~-P~~~~C~~lE-H;DÃ~~ÃR-BÕÑ$- 1 LITHOLOGY SAN D/SAN DSTON E- TRANSLUCENT. LIGHT GRAY, CLEAR, VERY FINE TO FINE GRAIN, ROUND TO SUBANGULAR, MODERATELY WELL SORTED. PREDOMINATELY UNCONSOLIDATED QUARTZ, TRACE GLAUCONITE, OCCASIONALLY FRIABLE SLIGHTLY CALCAREOUS LIGHT GRAY SANDSTONE. ~ ~ '" SHOW EVALUATION BRIGHT AND PALE YELLOW - WHITE FLUORESCENCE IN 90% OF SAMPLE CUTTINGS (FROM 9360 TO 9375) FLASH YELLOW - WHITE CUT FLUORESCENCE. t .1 GOOD OIL SHOW - APPROXIMATELY 35 GRAVITY OIL FROM FLUORESCENCE EVALUATION IN SAG RIVER. REMARKS I GAS ANALYSIS FROM STEAM STILL RATIO ANALYSIS OF C1-C5 , READINGS INDICATE OIL IN THIS ZONE. GOOD GAS READINGS AND GOOD SAMPLE QUALITY. j MWD RESISTIVITY READINGS RELATIVELY LOW 6-8 OHM-M. HYDROCARBON RATIOS ~ ~ ..£.L ~ ffi) C;> C3 C4 C5 4D 3D :m NONPROOlJC-1VF 1m ./ 8) fÐ ? 4) 3) GAS a) 10 8 6 ""'- . ulL 4 3 2 1 HYDROCARBON RATIOS ~ ..£.t. ..£.L ~ 5D c7 c3 c4 c5 Ð) 3D :m NON~nlJC1WF 1m 8) fÐ ~ , 4) 3) eA3 a) 10 8 6 4 3 ull 2 l ( I ~~~~~:-~~~ LOGGING SYSTEMS ~ A ŒESSER tÐJSlFES COfJPNl'( 1 Operator BP EXPLORATION Well Name NORTHWEST EILEEN 2-01 · Location PRUDHOE BAY UNIT l [ 1 ~ DEPTH 9580 It. GAS ~ ~nits 407 MUD CHLORIDES (ppm) 29000 ------------------------------------------------------- FLOWLINE SUCTION _ SHOW ppm ppm - ppm (Steam Still ppm's in 1000'5) HYDROCARBON RATIOS C 1 10,100 222 = 9,878 C 1 /C 2 = 12 ( c 2 830 20 = 810 13 C 1 Ie 3 = C 3 765 25 = 740 C 4 1 ,1 32 62 = 1 ,070 C 1 / C 4 = 9 C 5 1 .21 3 1 09 = 1 ,1 04 C 1 / C 5 = 9 - P~~~~~~1~Ñ - [j~¡; -ŒîO~L- - [j~~;E~- -Ö- ~~~-~~~~~C~~L-E-~;D~~~;~B~Ñ;- .,)' ~ DEPTH 9588 ft. GAS ~ ~nits 424 MUD CHLORIDES (ppm) 29000 ----RõwimË----šÜëTIõÑ-~---ŠHÕW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS r C 1 15,600 222 = 15,378 C 1 /C 2 = 12 C 2 1,270 20 = 1,250 C 1 IC 3 = 14 C 3 1 ,1 40 25 = 1 ,11 5 C 4 1.766 62 = 1.704 C 1 IC 4 = 9 C 5 1.962 109 = 1,853 C 1 /C 5 = 8 .\ - P~~~~~~I~Ñ - [j~¡; -Œi~~l- -[j~~TE~- -cf ~~~.~~~D~C~~L-E-HyD~~~;~B~Ñ$- T LITHOLOGY SAND/SANDSTONE- TRANSLUCENT. LIGHT GRAY. CLEAR. WHITE OCCASIONALLY. VERY FINE TO LOWER MEDIUM GRAIN, ROUND TO _ SUBANGULAR, POORLY SORTED, PREDOMINATELY UNCONSOLIDAT- ED QUARTZ, OCCASIONALLY FRIABLE SILlCEOUSL Y CEMENTED SANDSTONE, TRIPOLlTIC CHERT. 2DNE PfK)[)lJCllON CONTACT DEP11i (" Show Report 9A Part B Depth Interval 9575 to 9605 True Vert.Depth 8936 to 8970 Prepared by J. PATTON Delivered to HARRY HAYWOOD Date 4/19/98 Ti m e o GAS IX] Oil o WAlER o NON-PRODUCIBLE HYDROCARBONS Gas/Oil ft. Gas/Water ___________________________________________________________________________a Oil/Water ft. . - SHOW EVALUATION PALE AND BRIGHT YELLOW FLUORESCENCE, STREAMING YELLOW CUT FLUORESCENCE FROM SANDSTONE, SLIGHT YELLOW-WHITE HALO CUT FLUORESCENCE FROM BATCH SAMPLE. J j[ FAIR OIL SHOW EVALUATION IN IVISHAK, FEMARKS II GAS ANALYSIS FROM STEAM STILL RATIO ANALYSIS OF C1-C5 READINGS INDICATE OIL IN THIS ZONE. FAIR GAS READINGS AND GOOD SAMPLE QUALITY. II ¡ MWD RESISTIVITY READINGS AT 10-13 OHM-M. I ft. 1m m· m, 4) 3). :D 10 8 6 4 3 2 "r 5D C) 3D HYDROCARBON RATIOS .s. .s. .s. ~ c.,2 c3 c4 c5 æo NON~nIJCIVF 1m m m ./ 4) 3) BAS :D 10 8 6 4 3 2 ulL 5D C) 3D æo HYDROCARBON RATIOS ..£.L ..£.L ~ ..£.L c7 c3 c4 c5 NONP-1001 JCllVF --/ -....- ~ -s ull 11 ~ ~ r ~~~~~=~~~ LOGGING SYSTEMS A I:J£SSER IDJSTAES COWPÞNf '"J' ::>perator BP EXPLORATION ¡ Nell Name NORTHWEST EILEEN 2-01 1 Location PRUDHOE BAY UNIT 2DNE PRXX.JCTlON CONTACT DEPTH DGAS IX] OIL IX] WATER D NQtHJRX)lJCIBLE HYDROCARBONS (' Show Report 9 B Part 8 Depth Interval 9605 to 9635 True Vert.Depth 8970 to 8995 Prepared by J. PATTON Delivered to HARRY HAYWOOD Date 4/19/98 Time Gas/Water ---------------------------------------------------------------------------- 9620 Gas/Oil ft. ,; i 5 I 9628 ft 0 % ~ DEPTH . GAS Œ] units 268 MUD CHLORIDES (ppm) 29000 ----~ÕWi~È----ŠUCTIÕÑ-::--SHÖW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS ..: C 1 2,740 222 = 2,518 C 1 / C 2 = 24 I C 2 1 23 20 = 1 03 C 1 IC 3 = 31 C 3 107 25 = 82 C 4 241 62 = 179 C 1 IC 4 = 14 C S 425 109 = 316 C 1 /C 5 = 8 - p~~ä~~~I~Ñ - [j~;s- -Õ~~L- - Œj~~;E~- -0 ~~~-~~~~~~~CE-'¡;D-RÕëÃR-BÕÑS- ~ DEPTH 9632 ft. GAS DI'X1 % "t 106 MUD CHLORIDES (ppm) 29000 ~ Un! 5 ----~ÕWi~È----SUCTIÕÑ-~---$HÕW-------------------------- ppm ppm - ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 2,420 222 = 2.198 C 1 I C 2 = 26 C 2 105 20 = 85 C 1 IC 3 = 31 C 3 97 25 = 72 , C 4 211 62 = 1 49 C 1 I C 4 = 15 C 5 414 109 = 305 C 1 I C s = 7 ì - P~~~ï~~lgÑ - [j~¡S- -Ö~~l- - Œj~~;E~- -0 ~~~.~~~~~~~LE-H'¡DÃõëÃR-BÕÑS- ..¡ LITHOLOGY .." SANDSTONE- BUFF. WHITE. CREAM. VERY FINE TO LOWER MEDIUM GRAIN. PREDOMINATELY FINE GRAIN. SUBANGULAR TO ROUND. MODERATELY SORTED QUARTZ. MEDIUM TO WELL CEMENTED WITH SILICEOUS CEMENT. - SHOW EVALUATION PALE YELLOW MINERAL FLUORESCENCE, OVERALL - NO CUT FLUORESCENCE, OCCASIONAL YELLOW FLUORESCENCE AND OCCASIONAL YELLOW-WHITE CRUSH CUT FLUORESCENCE. - POOR OIL SHOW. ZONE APPEARS WATER SATURATED - WET BELOW 9615. ÆMARKS GAS ANALYSIS FROM STEAM STILL RATIO ANALYSIS OF C1-C5 INDICATES WATER IN ZONE RELATIVE TO 9628+. LOW GAS OVERALL READINGS. SOME OIL PRESENT IN 9605-9615. RESISTIVITY READINGS DECREASED FROM 7 TO 3 OHM-METERS AT 9620 INDICATING OIL WATER CONTACT. '" ft. Oil/Water ft. !ill 4D 3D aD HYDROCARBON RATIOS ..£L ..£L ...£.1. .s. C:; C3 C4 C5 NON~nlJCTIVF 100 8) m ../ 4) 3) :;n 10 8 6 4 3 ulL 2 !ill 4D 3D aD HYDROCARBON RATIOS ..£.L .s. ..£.1.. ..£.L C:; C3 C4 Cs NONIXtOOlJCIVF 100 8) m --/ -- " 4) 3) .s»£ :;n 10 8 6 4 3 ulL 2 PIXLER's PREMISES for LOGGING SYSTEMS SHOW EVALUATIONS , ~\ l .1 J I II ..J . '\ 1>. I I 1. L L ~. 1_.- 1- - L- I - 1.- IJI" l (, (' '", I ..' ~ .. ". ,.. ~...' ....w1.o.t .... t: . ' .:' (;' " ~~.~"1.:."!~ ..~ 'r ", OJ' '" -, " ,", . ....-iIo . . ' ~' /:~,:, '. , í';í ;. 'f-'" '?"" ~ ; ~, ' t'"f:' k..~~. ,~..~..t ~~'J?!'.. Formation Evaluation by Analysis of Hydrocarbon Ratios .. ~ B. O. Pixler, SPE-AIME, Baroid Div. National Lead Co. I, ~ 'r '.. 1 Introduction Mud logging was first offered commercially in Aug., 1939. This logging method quickly gained favor among many operators because the type of fluid in the formation could be determined within minutes after the formation was drilled. The presence and magni- tude of the methane show was and' is the most im- portant factor in mud log interpretation. Howevèr this magnitude in some instances was improperly understood, and as a consequence some operators still do not use mud logging, even though the early technique frequently made the difference between a successful well and an abandoned hole. Both the "hot wire" log of gas combustibles in the sample and the percent-of-gas log obtained with the conventional gas trap and the gas chromatograph indicate only that the reservoir in question contains hydrocarbons. These methods do not necessarily indicate the quantitative amounts of the various hydrocarbons in the mud. The addition of a new Steam Still-Reflux gas sam- pling system to gas chromatography enables accurate determination of the composition of the mud gas sample. A knowledge of gas composition makes it possible to establish the relationship of methane to the heavier hydrocarbon shows. An awareness of this relationship led to a new, additional mud log inter- pretative technique that permits relating the quanti- tative amounts of methane (Cl), ethane (C:!), pro- pane (C3), butane (C.), and pentane' (C:;) to in-place reservoir fluid content. ~ ' - } ¡ ~ J t » II II II A long-accepted premise is that as formations are drilled, the drilling mud filtrate partially flushes the formation fluid ahead of the bit. It was generally thought that the formations were flushed to an irre- ducible minimum - generally considered to be about 30 percent of in-place fluid. Experience in mud log- ging, however, has shown that this rarely happens. This partial flushing does not prevent mud logging from successfully determining productive or non- productive formations. Experienced logging engi- neers, in possession of quantitative gas analyses, make interpretations that take into account the flushing that results in rocks of various permeabilities, the effect of overbalanced mud weight and the effect of initial filtrate loss. Method Ordinarily, when formation cuttings are drilled they retain much of the fonnation pore fluid. This fluid is released to the mud column as the cuttings travel up the annulus. Most of the formation fluid in the cut- tings will be "produced" into the drilling mud during the top 500 ft of hole travel. Conventionally, a mud sample is diverted to a mechanically operated gas trap to obtain a sample of the gas in the mud. The effi· ciency of this trap is from 15 to 70 percent, depending upon the gel strength of the mud, the amount of mud flowing through the trap and the rotation speed of the trap impeller. The magnitude of the conventional The ratio of methane to the heavier hydrocarbon components - ethane, propane, butane, and pentane - is indicative of gas, oil alld water productive potential. The Steam Still-Refiux Unit, used in conjunction with 112Ud logs and gas chromatographs yields a quantitative analysis from which this ratio can be plotted. " ." r I ¡It,ll (," t; ') gas show. is, therefore, quantitative only to the air-gas sample obtained. The sample is accurately analyzed by the gas chromatograph; but, because the sample furnished by the conventional gas trap represents only a fraction of the gas present in the mud, and because that fraction is not representative of the total gases in the mud, the results are still only qualitative. When the Steam Still-Reflux Unit is used to obtain the gas sample, the gas sample will represent almost 1 ÖO percent of the hydrocarbon fractions C1 through C5 that were in the mud sample. This enables the chromatograph analysis to be related quantitatively to the mud, and the readings to be reported as parts per million of each hydrocarbon vapor (C1 through C&) to mud volume. , Because the cuttings from a particular formation uproduce" the gas they contain into the drilling mud, it was reasonable to assume that this same formation, if completed, would produce gases of a .similar com- position. This assumption led to a comparison of ppm Logs of hydrocarbon vapors with sinúlar data from producing wells. Plots were made of the ratio of methane to each of the heavier hydrocarbons from many analyses of wellhead samples. These plots were compared with plots, made from ppm Logs, of gas in mud. Both groups of plots showed definite patterns between (1) the magnitude of the ratios of methane to each of the heavier hydrocarbons, and (2) the slope of the lines of the plotted ratios. These, in tum, indicate productive potential and reservoir permeability . The Steam Still-Reflux Unit. consists of a small steam boiler, mud-injection port, mud-steam mixing chamber, Reflux-Condensing Unit and a gas-extrac- tion port. Five mI of mud are injected into the purged mud-steam mixing chamber. The mud is rolled with 2,000 to 4,000 volumes of steam. The hydrocarbons (C1 through C5) extracted from the mud are collected 400 300 200 CD MISSISSIPPIAN Oil RESERVOIR ® SilURIAN GAS·CONDENSATE RESERVOIR ® ORDOVICIAN GAS-CONDENSATE RESERVOIR @ LOWER ORDOVICIAN GAS AND WATER 100 80 60 40- 30 20 10 8 6 4- - 3-' 2-- Ct fL C2 C3 C. C5 HYDROCAR BON RATIOS Fig. I-Hydrocarbon ratio plots obtained from wellhead sample analyses data, limestone reservoirs, Rocky Mountain area. 1,"1, ) at the Reflux-Condensing Unit, withdrawn with a syringe, diluted to the standard chromatograph sam- ple size and injected into the chromatograph for analysis. The Reflux-Condensing Unit removes only the lighter paraffin series hydrocarbons from the mud sample tested. For example, if the mud contains diesel oil, the more complex hydrocarbons - CG and above - condense and drop back into the mud-steam mix- ing chamber. Therefore, regardless of whether the fluid phase of the mud is oil or water, the gas sample analyzecl contains· only the light fractions through CIi, and the analysis is representative of the formation gas. The full importance of determining formation gas composition has not always been apparent. At first it was observed that if the magnitude of butane in the mud was greater than the magnitude of either propane or ethane, the zone in question would pro- duce water and hydrocarbons. Later, the ratios of methane to each of the heavier hydrocarbon com- ponents were plotted on semilog paper. Hydrocarbon ratio plots obtained from ppm Logs and available data from wellhead gas sample analyses were com- pared. The comparison of the plots from ppm Logs and wellhead gas analysis data showed a striking cor- relation. The correlation demonstrated that ppm Logs made with Steam Still-Reflux samples could be in- terpreted in terms of in-place formation content. . The magnitude of the methane-to-ethane ratio de- termines if the reservoir contains gas or oil or if it is nonproductive. The slope of the line of the ratio plot of C1/Ct, Ct/C., C1/C., and C1/CI indicates whether the reservoir will produce hydrocarbons or hydro- carbons and water. Positive line slopes indicate pro- duction; negative slopes indicate water-bearing for- mations. An undersaturated reservoir may show a negative slope, but such occurrences are rare. The ratio plots may not be definitive for low permeabiüty zones, but unusually steep plots indicate tight zones. 400! 1"" - 1 '---;-".. - ì 300-- ¡I,. , . I 200---' --- I <D Gas-condensate. Frio Sand, , ' __' Hida1io County, Texas. analysis 100: _'u I from wellhead sample. 40': ' - ,1 from producin¡ well sample. 30~y ® State tract 49 No.1 well, Nueces 20i ::, County. Texas. 12.690' section. analysis : ' : from gas show on øtJtrl Log. , 10i ' 8_ I. 6' , 4; , ~ ~¡ ¡ --~_.~ fJ.. £L £L S. c:, ~ C. ~ HYDROCARBON RATIOS Fig. 2-Hydrocarbon ratio plots, productive reservoirs. South Texas. JOURNAl OF PFTROI Ft 't..1 TF("H1\:OIO(ìY ] I I ! .1 I 1 I , I :.:':1 TI "I II I i -I I] - ] i >,:: I ~±J I I I I 1 'í ( " ~' ~ A ratio of CalC: between 2 and 15 indicates oil. A ratio of C1/C: between 15 and 65 indicates gas. The lower the Cl/C~ ratio, the richer the gas or the lower the oil gravity. If the ratio of C1/C: is below about 2 or above about 65 the zone is nonproductive. Field Examples Fig. 1 sþows average hydrocarbon ratio plots from limestone reservoirs in the Rocky Mountain area. Plot 1 is derived from analyses of gases from Mis- sissippian oil-producing reservoirs. The C1/C: ratio is 3.5. The slope of the line is positive and not steep. Plot 2 was obtained from analyses of gases from wells producing gas-condensate from the Silurian. The C1/C: ratio is 12; the line slope is again positive and not steep. Plot 3 is from gas-condensate wells pro- ducing from the Ordovician. The C1/C: ratio is 15 and, again, the slope of the line is not steep; all three plots show slopes favorable for production. . Plot 4 shows ratios obtained from an analysis of gas from the Lower Ordovician, which produced gas and water. The plot shows a negative slope of the section from the C'dC.. ratio to the CdCð ratio. Many tests have verified the fact that if a ratio plot shows a negative slope, the zone in question is water-bearing. Fig. 2 shows plotted hydrocarbon ratios for pro- ductive reservoirs in South Texas. Plot 1 was made from an analysis of a wellhead sample of gas- condensate produced from a Frio sand, Hidalgo County. The production is rich in liquid hydrocar- bons as indicated by the low C1/C: ratio. Plot 2 is from an analysis of a wellhead gas sample from an 11,000-ft oil reservoir, North Lindsey field. The pentane was not reported, but the low C1/C: ratio indicates oil production. Plot 3 was obtained from a gas show at 12,690 ft on the ppm Log of the State Tract 49 No.1 Well, Nueces County, Tex. Formation tests resulted in gas production. 'I 'I I r ~i \ ¡.. r ;( ~ .t ,... I 'I ¡I II II II II II II 8000: - 6000:' 4000 3000 2000 .:: -. ...::-=- _-.== CD R.A. TALLY NO.1 WELL. VICTORIA COUNTY. TEXAS - .-- .- ® STATE TRACT 49 NO.1 WELL. NUECES COUNTY. TEXAS .. ,,:.. _=-:._-.. - DEPTH 8060' ® STATE TRACT 49 No.1 WELL. NUECES COUNTY. TEXAS ' DEPTH 9130' _ ® A. KOVAR No.1 WELL. VICTORIA COUNTY. TEXAS DEPTH 10120' . . ~8=-=.--- / 20 - -Q) 10-;·- - ~ ::.' -- =---- 4--- 3-'-- 2 - . -- .s. s. c- S. C: c) c. c~ HYDROCARBON RATIOS Fig. 3-Hydrocarbon ratio plots, nonproductive reservoirs. South Texas-analyses from gas shows on ppm Logs. II"'r 1 I) (,l) (' Experience shows that if the C1/C: ratio is above 65 the zone is too tight for commercial production. Fig. 3 shows the ratio plots obtained from ppm Logs on Texas Gulf Coast wells that were nonproductive in the zones of interest. Plot 1 is from the ppm Log of the R. A. Tally No.1 Well, Victoria County, Tex. The C1/C: ratio was 470. The zone was tested ex- tensively but it was a low penneability reservoir that could not be commercially completed. Plots 2 and 3 are from the State Tract 49 No. 1 Well, Nueces County, Tex. Plot 2 was from a sand encountered at about 8,060 ft. The relatively high ratios of C1/C2, C1/C3, C1/C., and C1/Cð indicated that the zone was nonproductive because of the low penneability. This was subsequently verified by testing. Plot 3 was ob- tained from a sand at 9,130 ft. The negative slope of the ratio plot, C1/C: to C1/CS, indicated that the zone was water-bearing. Subsequent fonnation tests showed water and non-commercial amounts of gas. , Plot 4 was obtained from the ppm Log of the Kovar No.1 Well, Victoria County, Tex. The sand encoun- tered from which the plot was made is at 10,120 it. The gas show appeared to be good, but a negative slope of the CI/Ca ratio to the CI/C. ratio was posi- tive identification of a water-bearing formation. Evaluation Technique It is apparent that with this evaluation system, poten- tial production can be accurately predicted. The only significant time lapse between penetration of the formation and evaluation of its productive possibili- ties is the time required to pump the mud from the bottom of the hole to the surface and analyze it by the Steam Still-Reflux and Chromatograph method. Fig. 4 shows the evaluation technique, which may be described as follows. First, record the net increase of each gas com- ponent over the background gas; next, plot the ratios 400' 300 200 CD Use only gas increase over I --,- ~ background. ! i· ø Plot ratios on lines indicated. I <ID Evaluate section for probable NONPRODUCTIVE . production as indicated by the plotted ;#1- curve within the following limits: (a) Productive dry gas zones may show only C. but abnormally high C. only shows are usually indicative of salt water. (b) If the C,/C, ratio is low in the oil sec~;on and the C1/C. ratio is high in the gas section the zone is probably nonproductive. (c) If any ratio (C,/C~ excepted if oil IS used in the mud) is lower than a preceding ratio the zone IS probably nonproductive. For example. if C,/C. is Jess than C,/Cs the zone IS probably wet. (d) The ratios may not be definitive for lOW permeability zones. however steep ratio plots may indicate tight zones, 100 BC ---:r' 60 .. 40 -GAS 30 20 -::__-~--- 10 8 6_01l 4 3 2_________ _____ NONPRODUCTIVE I i I £. .s. .s. .s. C: CJ C. C, HYDROCARBON RATIOS Fig. 4-ppm Log and report form for evaluation of show. hf, ": ) CJ/C;:, CI/CI' CjC~, C./C;, on the ratio lines as indicated. Then evaluate, within the following limits, the section in question for probable production as indicated by the plotted curve: 1. Productive dry gas zones may show only Ch but abnormally high shows of C. only are usually indicative of salt water. 2. If the C1/C:! ratio is low in the oil section and the CJ/C~ ratio is high in the gas section the zone is probably nonproductive. 3. If any ratio (C1/C:¡ excepted if oil is used in the mud) is lower than a preceding ratio, the zone is probably nonproductive. For example, if C1/C" is less than CJ/C:1, the zone is probably water-bearing. 4. The ratios may not be definitive for low perme- ability zones; however, steep ratio plots may indicate tight zones. ' Application The ppm Log is only one of many toöls that are ordinarily used for formation evaluation. But in many instances, the ppm Log has furnished the vital infor- mation necessary to make the final decision on a well. One well drilled in inland waters of Louisiana had ppm LOG ) what appeared on the ppm Log to be a good sand body, but the ppm Log showed only a nominal in- crease in gas. After the sand was penetrated and the well deepened, hole trouble was encountered. No other information of interest was available on the sand. The cost of the side-tracking to investigate the sand was sizable. Tight hole conditions and the low magnitude of the gas show indicated that the sand had good permeability and that possibly formation hydrocarbons had been flushed ahead of the bit. A plot of the hydrocarbon ratios indicated oil produc- tion. Therefore, at considerable expense, the sand was investigated and a new oil field was found. An interesting well recently drilled in St. Martin Parish, La., was the No.1 51. Martin Bank and Trust located on the southeast flank of the Anse La Butte Dome. A good sand encountered at about 8,000 ft showed oil, but the negative slope of the ratio plot indicated that the sand was water-bearing. The well was deepened to approximately 9,600 ft. One of the partners, a successful independent with a talent for finding oil by "feel" and by prudent use of the latest technology, decided that the" formations in which the well was being drilled were tilted to almost vertical. 400 300 200 s. ~ C1 Cs C1 ~ fL C, DR 75 50 25 C1 C2 C3 C, Cs 10M ª!L .5M .5M .5M - L CL-26f ~ -¡] ~.1 CL-26001 .- . 15 IrX20 IXIO CL-12aoif:l: , L-2~ ~ I ;, HYDROCARBON RATIOS C1 C1 ~ C, 62 78 14 59 7.4 46 9.1 56 11· 70 15 54 ( ""'- "'" PLOT 1 2 3 4 5 6 s.. C2 26 8.6 5.6 6.8 5.4 4.5 100 6 /~1 NONPRODUCTIVE %4 __ff_32 " "'" ,. 80- -"'" - -"'" . ; ~ 60 -GAY 40, 1 30r 20-- ~ (r I s.. C5 155 118 106 130 193 254 I 10-'·' a=- 6' 4 1-.. 41 6 3-01L 2 I I NONPRODUCTIVE I I I ..1, " Fig. 5-ppm Log and hydrocarbon ratio plots, No.1 St. Martin Bank and Trust Well, St. Martin Parish, La. lOt 'R~Al. OF PFTRO! Ft '\f TFCH~01.0GY - I I I I I ". I :- I \.~." ,j c I i I I ) I I _~ J t!::J ) I I I I I II. t, J \. ;<: ,~ ~ h "j ;:> 1\ i, 1 > J 1 , ,. ,( , , j JI 1 II III ( On his recommendaion the well was plugged back to about 7,000 ft and sidetracked. The sand that was drilled at 8,000 't in the first hole was encountered in the directional hole at approximately 7,400 It and the entire sand was hydrocarbon saturated. The ppm Log and the ratio plots from the sand in the sidetrack hole are shown in Fig. 5. Table 1 shows the mud gas components related to percent of total gas. In actual practice the ppm gas shows obtained from the ppm Log are not converted to percent of total gas; but note the general decrease in percent methane in the lower section of the sand compared with that in the upper section. The magnitude of the gas show in the straight hole and in the sidetrack hole was significant. An accurate determination, how- ever, of the composition of the gas in both cases led to correct conclusions on the potential productivity of the sand at the different depths in each hole. Note that the ratio Plot 1 at the top of the sand indicates a gas cap. As shown in Table 1, the gas was 93.1 percent methane. Subsequent plots indicated that production would be oil. In each of these cases the C1/C: ratio was less than 9. The lowest ratio, 4.5, is shown in Plot 6, which was made from the show at ppm LOG C1 C2C3C4CS 100 10M 2M 2M 2M 2M 10100 ~)~ l T .............)'Y . ~~~ \ I' ~f¡' r" '"'" .:}.:.' ~ < '» ~ ....' I 10200 _. <\ii - j i~~ { ~ 10400.\ ç- ~,;:¡~'; ~ ~~ 105oo~,;'~:i ~ C' 1O~~~1(, ~ ~ ~fl~~r·~ ~ ~ ~~ r ~ ~I -,: i ;j DR 10300 ~ r ~ I > ( TABLE I-MUD GAS COMPONENTS, PERCENT OF TOTAL GAS Depth (ft) 7,460 7,475 7.485 7,490 7,500 7,515 ~ 93.1 82.4 74.4 78.0 77.0 76.1 ~ C, C. 3.6 1.5 1.2 9.6 5.9 1.4 13.3 10.0 1.6 11.4 8.6 1.4 14.3 7.2 1.1 17.1 5.1 1.4 ~ 0.6 0.7 0.7 0.6 0.4 0.3 the bottom of the sand. Another example of the application of the ppm Log is No. 1 State Tract 19 8 Well, Aransas County, Tex. Many sands were encountered showing the presence of hydrocarbons. The logging crew sub- nútted more than 60 ratio plots to the operator during the drilling of the well. In almost all instances subse- quent information verified the logging engineers' pre- di~tions of probable productivity based on the raûo plots. Fig. 6 shows a section of the ppm Log and the ratio plots for this well. The gas composition relating the percent of each gas component to the total gas is , shown in Table 2. Gas condensate production is indi-~' C1 C1 C1 ..---- 10 8' . 6 -01 L 4 3' 2 NONPRODUCTIVE l' , I HYDROCARBON RATIOS C1 Cs ' 230 102 310 CO 185 C1 C1 C1 PLOT C2 C3 C4 1 18 71 84 2 20 61 92 3 19.5 78 233 4 16 93 232 5 19.3 58 115 " ." t ,,,/, 4\ Fig. 6--ppm Log and hydrocarbon ratio plots, No.1 State Tract 198 Well, Aransas County, Tex. (,r,o ) TABLE 2-MUD GAS COMPOSITION. PERCENT OF TOTAL GAS Depth C. C. ~ ~ eft) c. 10,11 0 92.0 5.2 1.3 1.1 0.4 10,115 92.0 4.6 1.5 1.0 0.9 10,450 93.3 4.8 1.2 0.4 0.3 10,520 92.8 5.8 1.0 0.4 0.0 11.305 92.3 4.8 1.6 0.8 0.5 cated by the ppm Log and ratio plots as shown. The zones are tight marine deposits - especially the 10,520-ft zone. Plot 4 has the steepest line slope; pentane was not present The slope of Plot 3 is steep. Plots 2 and 5 show more favorable (less steep) line slopes. The electric log and subsequent formation tests made of each zone indicated probable produc- tion. The well was completed as a gas condensate producer in the 11 ,3OO-ft section, which is. the section plotted as No. S. Conclusions Only qualitative shows of hydrocarbons in the mud can be derived from conventional mud logs. If chromatography is used, only a general indication of in-place gas composition is obtainable. Such hydro- carbon shows may be reported as units of gas or percent hydrocarbons or parts per mil1ion of gas in the air-gas mixture tested. Only the presence in rela- tive amounts, not the actual quantity, of hydrocar- (, .." ) bons in mud is indicated, and other supplemental information may be necessary to evaluate the forma- tion in terms of potential productivity. However, if the composition of the gas sample obtained from the mud is representative of the in-place formation gas, then the gas analysis is accurate. The use of the Steam Still-Reflux Unit makes possible a report of forma- tion gas composition on the ppm Log. Meaningful ratio plots of gas composition can then be made. Even though many factors affect the amount of reservoir fluid released to the drilling mud, reservoir potential productive capabilities can be determined by a study of the ratio of methane to each of the heavier hydro- carbon components. The hydrocarbon ratio plot is a unique technique and provides the operator with new information for evaluating productive possibilities of exploratory wens. Computer programs involving percent gas in mud (ppm Log) and gas composition are being used in special cases to determine reservoir potential produc- tion. The use of computers in mud log interpretation, although new, will contribute significantly towards a better application of the data shown on the ppm Log. .TPT Original manuscript received In Society of Petroleum Ensinee,. office Aug. 5. 1968. Revised manuscript received March 5, 1969. Paper (SPE 2254) was presented at SPE 43rd Annual Fall Meetln. held In Houston, Tex., Sept. 29'()ct. 2, 1968. C CoPyrllht 1969 American Institute of Mlnlns, MetallurKlcal, and Petroleum Engl. nMrs, Inc. In, 1~"", ()}.: N:TR()I FI'\f T¡.:rH,nl ()(ìY 1 ] 1 ] ., ) OJ J I I .I :,') ", .,., ~c .J ) I I I I I · '11( ,;¡ "f 1. -+. io. fl ... ~r 1 ." ¡ ?' " , ' t l' .~ '.... !A- .f' , "~ I ~ '! I I I ~ }I I( II ( ( GUIDELINES FOR USING PPM RATIO PLOTS TO EVALUATE HYRDROCARBON SHOWS (REVISED 9/27/89 TO COVER "METHANE ONLY" SHOWS) A show that has only methane or primarily methane CAN be indicative of a productive , zone. Many wells in the Gulf of Mexico produce only methane or methane and saltwater. (The commercial productivity of a GAS/SAL 1W ATER well is based on the relative "proportions of gas versus saltwater saturations determined by resistivity measurements.) a) Fill out a SHOW REPORT in a zone that meets the requirements of a show based on the definition even if it contains methane onlv. b) State in the LOGGER'S OPINION that this is a "methane only" show. c) Also state that Cl only CAN be indicative of dry-gas production BUT usually has saltwater associated with it. d) After making the ppm plot and observing for a neeative slope. checking for a chloride increase (by titration or conductivity) OR observing a resistivitv decrease on an MWD log, appropriately "X" the GAS or GAS and WATER indication in the ZONE PRODUCTION ANALYSIS paragraph on page 1, including the depth of the water contact if detectable and the footage of the show. 2. C1/C2 between 2 and 15 indicates Oll... You should see some fluorescence in the mud or cuttings but not necessarilv. a) -Values in the range of 2 . 4 indicate low gravity oil (10 . 15 on the API gravity comparison scale.) A low gravity oil can have a bronze, brown or dull' orange fluorescence and be very dark brown to black in color. b) Values in the range of 4"· 8 indicate medium gravity oil (15 . 35 on the API gravity comparison scale.) A medium gravity oil will have a cream to bright yellow fluorescence and be light to medium brown in color. c) Values in the range of 8 . 15 indicate high gravity oil (35+ on the APT gravity comparison scale.) A high gravity oil win have bright blue to blue-white fluorescence and be clear in color. SEE NOTE BELOW. 3. Cl/C2 ratios in the 15 to 6S range indicate GAS. Any fluorescence associated with a GAS zone indicates the presence of condensate. SEE NOTE BELOW. a) Values in the 15 .. 20 range indicates gas rich in heavies, C4 and C5 ppms, and would most likely be associated with condensace. b) Values in the 20 .. 50 range indicates gas rich in mid ranged hydrocarbons, C2 an~ C3 ppms. " ) ) 3. c) Values in the 50 - 65 range indicates gas rich in the lighter fraction, Cl ppms. NOTE: Cl/C2 ratios in the 10 - 20 range £ml indicate the presence of CONDENSATE or DISTILLATE. Indications would be the presence of bright yellow or blue white fluorescence OR cut. (Condensate is a hydrocarbon that is a GAS under the temperatures and pressures of the reservoir but "condenses" to a UQUID when it reaches the surface. It would compare to gasoline in appearance and physical characteristics and was in fact called "drip gas" in the early oilfield. 4. Cl/C2 ratios less than 2 and greater than 65 indicate NON-PRODUCIBLE HY.QROCARBONS. a) A hydrocarbon with a value less than 2 indicates an OIL with a gravity so low (the oil is very thick) that it can't be produced. b) A hydrocarbon with a value greater than 65 indicates a light GAS, mostly Cl, but the low permeability nature of the formation makes it non- producible. 5. The slope of the line of all plotted ratios indicates if the zone will produce hydrocarbons only OR hydrocarbons and water. Line slope also provides some indication as to the formation permeability. a) An all positive slope. up and to the right, indicate HYDROCARBONS ONLY. b) If ~ of the line segments have a negative slope. down and to the right, . HYDROCARBONS AND SALTWATER is indicated. Obviously, the mud chlorides SHOULD increase but not necessarllv. c) A steep line slope indicates reduced permeability AND the steeper the slope, the lower the permeability. Steep is a relative term BUT the dashed lines separating the GAS, OIL and N_ON-PRODUCIBLE areas of the graph are there for comparison. * On.. plots whose line slope is somewhat steeper than the MIDDLE dashed line indicate tow permeabititv. * On.. plots whose line slope is equal to or less than the MIDDLE dashed line indicate good permenbilitv. * GAS plots whose line slope is somewhat steeDer than the TOP dashed line indicate low permeahilitv. * GAS plots whose line slope is eaual to or less than the TOP dashed line indicate ~ood penneabiIitv. 1 .1 1 I ] ,.,...} .,' I /":,1 I ) , I J I '. J I >. } ::,..,J I I ) I ) I '[ [ DEPTH 143 OPERATION RIG REPAIR FOOTAGE 33 1 OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 ,If BACKGROUND CONNECTION TRIP -I FLOWLINE TEMP AVG GAS (units) 1 MAX GAS (units) 3 55 degrees F 1 CASING PORE PRESSURE 49 psi 8.5 FRACTURE PRESSURE NA psi ECD 55 psi 8.8 TIME ~ TYPE I WEIGHT IN ... FUNNEL VIS. PV/YP 1 :~LS - FIL T/CAKE API HP-HT ,~ Pm I Pf/Mf ! CHLORIDES ppm CALCIUM ppm ~' OIL/WATER/SOLIDS ! DAILY/CUM. COST j, . . i ~ ~ 1 J \¡~ 'I ~ ~ I ..r ¡ DP - CSG DP - HOLE DC - CSG DC - HOLE -'-: IOD-inche, ID-inehes :I.. 1 CAP-bbls/ft DISP-bbls/ft 11 LENGTH-ft J WEIGHT-Ibs/ft I MUD DATA 00:00 3-11 -98 SPUD 8.8 168 1 2/31 30/62 9.8 12.4 - 2/32 .4 .20/.40 500 60 0/96/4 LENGTH - FT. 5 X 20" 5X16" 5X 20 110 sper~ ,,-sun ( DRILLING SERVICES It:X3GING SYSTEMS A Dt:SSeI NJUSTRES NC. Cf:JWJÞNY APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTH WEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA AT DEPTH (feet) 143 SURVEY DATA LITHOLOGY 100% GRAVEL SAMPLE DEPTH 140 TRIP CHLORIDES LAG DOWN DP 20 LAG OFF BOTTOM 600 8 X 16" 33 FORMAllON PRESSURE DATA BOTTOM HOLE ppg 63 psi 8.5 ppg ppg 78 psi 10.5 ppg ppg 68 psi 8.8 ppg 8fT DATA BIT NO. 1 TYPE MA-1 JSL lADe CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT ROT HRS. .3 FOOTAGE 33 AVG ft/hr 110 GRADE HOLE DEV. COST/FT R PM 1 00 W 0 B 0/2 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .330 .2245 .278 48 DP HWDP 5.0 5.0 4.276 3.0 .0178 .0087 .0075 .0181 19.5 49 .1866 83 PIPE DATA DRILL STRING DC 8.0 2.875 .0080 .0542 143 147 NO. 1 DATE Mar 11 98 TIME 0001 FIELD/BLOCK AREA STATE DRILL RATE ft/hr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. P.B.U. NORTH SLOPE ALASKA 100 .45 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 75 FLOW RATE gal/min 654 PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT-VEL FT/MIN 350 400 CASING: CO ND DEPTH 110 20.0' 19.12 .355 .0334 110 94 REMARKS AND RECOMMENDATIONS J MW 8.8 GPM JETS " " RIG UP UNIT # 40070 ON POOL ARCTIC ALASKA RIG 8. RIG ACCEPTED 18:00 HRS. J DRILL TO 143', WORK ON RIG - REPAIR SWIVEL PACKING AND AUGER BEARING, I 11 ADT ft/mi = 2. ID 1 600 6X 12 4.22 80 2100 75/120 5/1 900 497 1465 710 90% - 3.7 /in2 psi at _stk/min psi at _stk/min ANN-VOL BBLS M/U BHA ON BIT NO.1. TAG UP AT 103' INSIDE CASING. sec/std t L. l DEPTH 900 OPERATION DRILLING FOOTAGE 757 .., OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA ... START DATE Mar 10 98 1 AVG MAX AT GAS GAS DEPTH (units) (units) (feet) BACKGROUND 15 22 900 CONNECTION TRIP 20 324 ~ FLOWLINE TEMP 65 degrees F -!' CASING ,¡,¡'" PORE PRESSURE 49 psi 8.5 FRACTURE PRESSURE NA psi ECD 72 psi 9.8 .:.. TIME TYPE WEIGHT IN .. FUNNEL VIS. PV/YP -.$ GELS pH ~ FIL T/CAKE API HP-HT '~I Pm Pf/Mf ... CHLORIDES ppm CALCIUM ppm ( OIL/WATER/SOLIDS DAILY/CUM. COST J,JI , 1 DP - CSG ~I ," I I. I DP - HOLE DC - HOLE '" I OD-inchos ! ID-inehes " I CAP-bbls/ft DISP-bbls/ft ~ LENGTH-ft ~, WEIGHT-Ibs/ft I MUD DATA 23:303-12-98 SPUD 9.7 90 17/30 26/42 8.8 12.8 - 2/32 .15 .10/.24 280 35 0/92/8 5 X 20' LENGTH - FT. 110 ( ( sperry-sun DRILLING SERVICES LCX3GING SYSTEMS A (FESSER NJUS1ŒS NC. ~MN APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTH WEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11 E FIELD/BLOCK AREA STATE 5X16" 532 LOGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM (â;)973.7 DS .40 DEG - AZ 220.8 30% CLAY - 70% SAND+GRAVEL 900 105 2200 DRILL RATE ft/hr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. 8X16" 258 FORMATION PRESSURE DATA BOTTOM HOLE ppg 398 psi 8.5 ppg ppg 505 psi 10.8 ppg ppg 393 psi 9.8 ppg NO. 2 DATE Mar 12 98 TIME 0001 P.B.U. NORTH SLOPE ALASKA 70 1.02 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft BIT DATA HYDRAULIC DATA BIT NO. 1 TYPE MA-1 JSL IADC CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT ROT HRS. 8.3 FOOTAGE 790 A VG ft/hr 95 GRADE HOLE DEV. .4 COST/FT 45 RPM 145 WOB 15/25 PUMPS 1. 101600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 71 FLOW RATE gal/min 640 PRESSURE psi PD SURF / OS psi ANN / BIT psi JET VELOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 DP 5.0 4.276 .0178 .0075 188 19.5 HWDP 5.0 3.0 .0087 .0181 454 49 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .330 42 CRIT -VEL FT/MIN 370 .2245 68 370 .1866 82 385 PIPE DATA DRILL STRING DC 8.0 2.875 .0080 .0542 258 147 CASING: COND DEPTH 110 20.0" 19.12 .355 .0334 110 94 REMARKS AND RECOMMENDATIONS 'MW 9.5 GPM JETS ~ I REPAIR CUTTINGS AUGER. DRILL TO 324'. POOH AND LAY DOWN HWDP. P/U BHA AND CONTINUE DRILLING. ¡., J1ADT ft/mi = 2. ID 1 600 6X 12 4.22 72 2400 75/355 5/2050 487 1564 765 85% - 3.8/in2 psi at _stk/min psi at _stk/min ANN-VOL BBLS sec/std If .:.. DEPTH 2110 OPERATION DRILLING '. FOOTAGE 1210 OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA .. START DATE Mar 10 98 1 BACKGROUND CONNECTION TRIP 45 \. FLOWLINE TEMP AVG GAS (units) 1100 65 AT DEPTH (feet) 1955 1955 1494 degrees F MAX GAS (units) 2433 2433 1 CASING PORE PRESSURE 49 psi 8.5 FRACTURE PRESSURE NA psi _IF ECD 61 psi 10.7 -.I TIME ! , TYPE WEIGHT IN .1 FUNNEL VIS. P V /YP J GELS pH >of FILT/CAKEAPI HP-HT Pm Pf/Mf ,,~I CHLORIDES ppm CALCIUM ppm , OIL/WATER/SOLIDS DAILY/CUM. COST ,..;.,J D P - CSG 5X20' DP - HOLE 5 X 16' "',' .;¡, I -,-,,:\ DC - HOLE 8X 16" OD-inehes ID-inehes ,~ CAP -bbls/ft DISP-bbls/ft ·r I LENGTH-ft J j WEIGHT-Ibs/ft MUD DATA 23:30 3-1 3-98 SPUD 10.6 80 1 8/26 14/42 14.0 - 2/32 DP 5.0 4.276 .0178 .0075 1398 19.5 LENGTH - FT. 110 1742 258 HWDP 5.0 3.0 .0087 .0181 454 49 ( Sperry-SUn DRILLING SERVICES LCK2GING SYSTEMS A ŒESSffi NJUSlŒS NC. cotv'PAN'f If ( NO. 3 DATE Mar 13 98 TIME 0001 P.B.U. NORTH SLOPE ALASKA 100 .77 FORMATION PRESSURE DATA BOTTOM HOLE ppg 1010 psi 9.2 ppg P P 9 1 229 psi 11 .2 P P 9 ppg 1174 psi 10.7 ppg OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA 2. 10 1 600 6 X 12 ,4.22 80 3000 75/440 10/2475 516 1900 985 82% - 4.7 /in2 psi at ~tk/min psi at _stk/min ANN-VOL BBLS REMARKS AND RECOMMENDATIONS : MW 10.2 GPM JETS ft/mi = sec/std I ..... I DRILL AHEAD WITH BIT NO.1. SLOW PENETRATION RATES IN PERMAFROST. DRILL TO 1493. CBU. SHORT TRIP 8 STANDS. MAX GAS , FROM TRIP = 45 UNITS. HIGH GAS READINGS RECORDED FROM SAND BEGINNING AT 1790' AFTER DRILLING THROUGH BASE OF PERMAFROST. ,MAS GAS = 2433 UNITS FROM CONNECTION @ 1955'. BACKGROUND GAS AVERAGING 1100 UNITS DRILLING BELOW ZONE CONTAINING 'I HYDRATES FROM 1790·1840'. JOHN PATTON APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTH WEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC19-T12N-R11E FIELD/BLOCK AREA STATE ...~ I ADT LOGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM (â)1809 DS .36 DEG - AZ 261 40% CLAY - 60% SAND+GRAVEL 2040 310 5100 DRILL RATE ft/hr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. BIT DATA BIT NO. TYPE lADe CODE SIZE JETS DEPTH OUT ROT HRS. FOOTAGE A VG ft/hr GRADE HOLE DEV. COST/FT RPM WOB 1 MA-1 JSL PUMPS 1. 101600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stkslmin 80 FLOW RATE gal/min 677 PRESSURE psi PO SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 16.0 1 5-1 5-1 0 20.1 2000 99 .4 43 140 1 0/25 ANNULAR DATA VOLUME BBLS/FT. .330 VELOCITY FT/MIN 44 CRIT-VEL FT/MIN 370 .2245 72 370 .1866 87 385 PIPE DATA DRILL STRING DC 8.0 2.875 .0080 .0542 258 147 CASING: COND DEPTH 110 20.0" 19.12 .355 .0334 110 94 f OPERATOR BP EXPLORATION ~ CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 l l 1. 'I -... DEPTH 2680 OPERATION TRIP FOOT AGE 570 BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG GAS (units) 400 1205 75 PORE PRESSURE 49 FRACTURE PRESSURE NA ECD 58 ~ TIME l TYPE WEIGHT IN . FUNNEL VIS. PV/YP GELS pH FIL T/CAKE API HP-HT 'I ~f;Mf .,.1 CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS ...J DAILY/CUM. COST D P - CSG ,.. ~ ~,cJ DP - HOLE DC - HOLE ~ OD-inches ID -inches CAP-bbls/ft DISP-bbls/ft LENGTH-ft ,,A WEIGHT-Ibs/ft ,1 MW 10.2 MUD DATA 20:003-14-98 SPUD 10.1 110 20/27 19/41 8.7 12.5 - 2/32 o .05/.35 300 40 0/89.4(10.6 5X 20' 5 X 16' 8X 16" DP 5.0 4.276 .0178 .0075 1968 19.5 GPM MAX GAS (units) 2000 2680 degrees F CASING psi 8.5 psi psi 10.2 LENGTH - FT. 110 2312 258 HWDP 5.0 3.0 .0087 .0181 454 49 JETS ( sperry-sun DRILLING SERVICES A CfESSER NJUSlfES NC. CONPÞN( t LOGGING SYSTEMS APPIJED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTH WEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC19-T12N-R11E FIELD/BLOCK AREA STATE NO. 4 DATE Mar 14 98 TIME 00 01 P.B.U. NORTH SLOPE ALASKA 85 .79 FORMA11ON PRESSURE DATA BOTTOM HOLE 1254 psi 9.0 1810 psi 13.0 1422 psi 11 0.2 933 OPEN HOLE psi 9.2 ppg psi ppg psi ppg 1950 MAX ft ft ft err DATA HYDRAUUC DATA 2. I D 1 600 6 X 12 4.22 81 2900 75/415 1 0/2400 517 1840 960 80% - 4.8/in2 psi at _stk/min psi at ~tk/min ANN-VOL BBLS sec/std DRILL AHEAD TO CASING POINT AT 2680'. LOW GRAVITY SOLIDS PROBLEM DEVELOPED WITH MUD SYSTEM DRilLING IN CLAY RICH FORMATION. MUD WEIGHT INCREASED TO 10.6-10.8 PPG. DILUTE MUD SYSTEM WITH WATER AND NEW MUD. CIRCULATE AND CONDITION AT 2680. SHORT TRIP TO 712. RIH. NO DRAG. CBU AND CONDITION HOLE WITH 10.1-10.2 PPG MUD. MAX GAS = 1205. BACKGROUND GAS :J REDUCED TO 400. POOH. JOHN PATTON LOGGING DATA AT DEPTH (feet) 2455 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM (@2632 DS .26 DEG - AZ 333 30% COAL - 40% CLAY - 30% SAND 2680 DRILL RATE ft/hr CORRECTED 'D' EXP. SHALE DENSITY g/ec EWR Res. ,~ ADT 405 6200 ppg ppg ppg ppg ppg ppg BIT NO. 1 TYPE MA-1 JSL IADC CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOTAGE 2570 AVG ft/hr 102 GRADE 2-2-E-1 HOLE DEV. .26 COST/FT 35 R P M 1 40 WOB 10/25 PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stksJmin 80 FLOW RATE gal/min 680 PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BITHP HP RATIO / HP/IN2 REDUCED 1 RATE 2 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .330 44 CRIT -VEL FT/MIN 275 .2245 72 275 .1866 87 300 PIPE DATA DRILL STRING DC 8.0 2.875 .0080 .0542 258 147 CASING: CO ND DEPTH 110 20.0' 19.12 .355 .0334 110 94 REMARKS AND RECOMMENDATIONS ftlmi = 1 DEPTH 2680 OPER.ATION NIPPLE DOWN ~ FOOTAGE 0 J OPERATOR ÇONTRACTOR . START DATE j :I .,r BACKGROUND CONNECTION TRIP FLOWLINE TEMP ~ ,.- BP EXPLORATION POOL ARCTiC ALASKA Mar 10 98 AVG GAS (units) 150 MAX GAS (units) 890 890 2680 degrees F 65 ,\ PORE PRESSURE 1250 FR.ACTURE PRE$$URE N.A J [CD 1812 CASING psi.9.0 p8i psi 13.0 " IOD-inche, : D -incheô ., CAP-bbls/ft D!$P-bbls/ft I LENGTH-it , WEIGHT-Ibs./ft I REMARKS AND RECOMMENDATIONS t MW 9.3 GPM JETS ftlmi = fRIG UP FOR RUNNING CASING. RUN AND LAND 13 3/S" - 6S LO/rT CASING. nil-I WITH DRILL PIPE. TAG STAO IN TOOL AT 2576' . '~ RIG UP CEMENT HEAD. CIRCULATE AND CONDITION HOLE. MAX GAS = 8DO UNITS. CEMENT IN PLACE AS PER WELL PROGRAM. P BUMP PLUG. LID CEMENT HEAD. POOH WITH DP. BLOW DOWN LINES. NIPPLE DOWN. CLEAN MUD PITS AND DISPLACE TO VAC TRUCK. f 'I ADT TIME :1 TYP[ WEIGHT IN " I FUNNEL VIS. PV/YP < I GELS ; pH F IL T ¡CAKE APi HP·HT '1' Pm ; Pf/Mf ''',1' CHLORIDES ppm CALCIUM ppm ,11 OIL/WATER/SOLIDS DAILY/CUM. COST ~ I ) DP - CSG "', I DP . HOLE , ;·.1 '" ~ I DC - HOLE MUD DATA 20:003-' 5-98 SPUD 10.1 44 13/6 1/2 8.0 11.0 - 2/32 o .05/.45 300 40 0/89.4/10.6 lENGTH - FT. 5 X 1 3 3/8 5 X 12.25' 8 X 1 2.25" DP 5.0 HWDP 5.0 4.275 3.0 .0087 .0178 .0075 .0181 19.5 49 JOliN PATTON AT DEPTH (teet) 2680 ( ~ sperry-sun DRTClING $[RVIC[$ lOGGING SYSTEMS A ŒE$SER NJUSTRES NC. COfÆ'ÞN( NO. 5 D,A TE Mar 15 ~8 TIME 00 01 APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTH WEST EILEEN 2-01 RiG N.AME RiG 8 LOC. SEC 19 - T12N . R11E FIELDíBLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA lOGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIO[$ LAG DOWN DP LAG OFF BOTTOM rã)2632 DS .26 DEG - AZ 333 30% COAL - 40% CLAY -30% SAND 2680 DRILL RAT[ ftJhr CORRECTED "D" EXP. SHALE DENSITY g/ce EWR Res. 85 .i9 FORMATION PRESSURE DATA BOTTOM HOLE ppg . 1254 psi 9.0 ppg ppg 181 0 p~i 13.0 ppg p p 9 1 422 psi 1 0.2 P P 9 OPEN HOLE psi ppg p8i ppg psi ppg ft it ft BIT DATA HYDRAUUC DATA BIT NO. 1 TYPE MA-1JSL IADC COD[ SIZE 16.0 JET$ 15-15-10 DEPTH OUT 2660 ROT HRS. 25.2 FOOTAGE 2570 .Å. VG fr/hr '02 GRADE 2-2-E-1 HOLE DEV. .26 cö$TlFT 35 RPM '140 WOB 10/25 to 1 600 6 X 12 4,22 2, to 1600 6 X 12 4,22 PUMPS 1. SIZE inches C.AP.ACITY gal/~tk PUMP RA TE ~tk8/min fLOW RATE gal,lmin PRESSURE psi PD SURF / OS psi ANN I BIT p:si JET VELOCITY ft/sec JET IMPACT Ibs BITHP HP RATIO I HP/IN2 REDUCED 1 RATE 2 STATIC p ~i at _:stk/min psi at _stklmin ANNULAR DATA VOLUME BBlSlFT. VELOCITY FTlMIN .1247 CRIT-VEl FT!MIN ANN-VOL BBlS .1215 .0836 PIPE DATA DRILL STRING DC 6.0 SURF 2576 1 3 3/8· 12.415 .1498 _.0240 CASING: COND DEPTH 110 20.0· 2.875 19.12 .0080 .355 .0542 .0334 1'0 94 68 147 sec/std 1 I DEPTH 2680' _OPERATION W/O TBL SPOOL FOOTAGE 0 OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 BACKGROUND I CONNECTION TRIP - FLOWLINE TEMP AVG GAS (units) o M AX AT GAS DEPTH (units) (feet) o 65 degrees F 1..'_ CASING _ PORE PRESSURE 1250 psi 9.0 FRACTURE PRESSURE NA psi , ECD 1812 psi 13.0 -.... TIME TYPE I WEIGHT IN _ FUNNEL VIS. PV/yP GELS pH FILT/CAKE API HP-HT Pm Pf/Mf ." CHLORIDES ppm CALCIUM ppm .. OIL/WATER/SOLIDS DAILY/CUM. COST .1 DP - CSG DP - HOLE ...., I DC - HOLE -,: I OO.inches '~ ID-inehes , I CAP-bbls/ft DISP-bbls/ft , LENGTH-ft ~ WEIGHT-Ibs/ft I MUD DATA 14:003-16-98 WATER 8.4 28 1/0 o , .0/.0 100 40 0/1 00/0 LENGTH - FT. 5X133/8 5 X 1 2.25' 8 X 1 2.25" DP 5.0 4.276 .0178 .0075 HWDP 5.0 3.0 .0087 .0181 { ( span :I-sun DRILLING SERVICES lOGGING SYSTEMS A IHSSER NJUSlFES NC. cotv'PNN NO. 6 DATE Mar 1698 TIME 0001 19.5 49 APPLJED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTH WEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC19-T12N-R11E FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA LOGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM @2632 DS .26 DEG - AZ 333 . 30% COAL - 40% CLAY - 30% SAND 2680 DRILL RATE ftJhr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. 85 .79 FORMAllON PRESSURE DATA BOTTOM HOLE ppg 1254 psi 9.0 ppg ppg 1810 psi 13.0 ppg ppg 1422 psi 10.2 ppg err DATA OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAULIC DATA 2. I D 1 600 6 X 12 4.22 BIT NO. 1 TYPE MA-1 JSL lADe CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOTAGE 2570 A VG ft/hr 102 GRADE 2-2-E-1 HOLE DEV. .26 COST /FT 35 R PM 1 40 WOB 10/25 PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min FLOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN I BIT psi JET VELOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 STATIC psi at _stk/min psi at _stk/min ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 CRIT -VEL FT/MIN ANN-VOL BBLS .1215 .0836 PIPE DATA DRILL STRING DC 8.0 2.875 .0080 .0542 SURF 2676 1 3 3/8" 1 2.41 5 .1498 .0240 CASING: CO ND DEPTH 110 20.0' 19.12 .355 .0334 110 94 147 68 REMARKS AND RECOMMENDATIONS F. MW 9.3 GPM JETS ftlm i = sec/std ~ - I NIPPLE DOWN. NIPPLE UP WELL HEAD + SPOOL + STACK. NO TEST ON METAL TO METAL ON STARTING HEAD. REMOVE STACK. WELD TBL TO STARTING HEAD. WORK ON TRIP TANK PUMP, DESANDER. AND DESILTER. CLEAN PITS. WORK ON TBL SPOOL. ~I lrAoT JOHN PATTON 1. I. 1 OPERATOR BP EXPLORATION . CONTRACTOR POOL ARCTIC ALASKA ST ART DATE Mar 1098 DEPTH 2680 OPERATION NIPPLE UP FOOTAGE 0 1 AVG GAS (units) o M AX AT GAS DEPTH (units) (feet) I. BACKGROUND CONNECTION TRIP FLOWLINE TEMP o 65 degrees F 1 CASING ...... PORE PRESSURE 1250 psi 9.0 FRACTURE PRESSURE NA psi ECD psi 1 l [ 1 1 MUD DATA TIME TYPE WEIGHT IN FUNNEL VIS. PV /YP GELS pH FILT/CAKE API HP+IT 14:003-16-98 WATER 8.4 28 1/0 Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST o .0/.0 100 40 0/1 00/0 LENGTH - FT. DP - CSG 5X133/8 DP - HOLE 5 X 1 2.25" -( ~) DC - HOLE 8 X 1 2.25" OD-inches ID -inches DP 5.0 4.276 .0178 .0075 HWDP 5.0 3.0 .0087 .0181 I.. CAP-bbls/ft DISP-bbls/ft LENGTH-ft WEIGHT-Ibs/ft ; 19.5 49 MW 9.3 GPM JETS WORK ON TBG SPOOL. ALLOW WELD TO COOL. NIPPLE UP BOP STACK. NIPPLE UP CHOKE & KILL LINES. _I -. ADT JOHN PATTON f lOGGING SYSTEMS spefrv-sun DRILLING SERVICES A ŒESSER NJUS1ŒS NC. COWPÞNf APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTH WEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOOGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM FIELD/BLOCK AREA STATE (ã)2632 OS .26 DEG - AZ 333 30% COAL - 40% CLAY - 30% SAND 2680 FORMATION PRESSURE DATA BOTTOM HOLE ppg 1254 psi 9.0 ppg ppg 1810 psi 13.0 ppg ppg psi ppg err DATA BIT NO. 1 TYPE MA-1 JSL IADC CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOTAGE 2570 A VG ft/hr 102 GRADE 2-2-E-1 HOLE DEV. .26 COST/FT 35 R PM 1 40 WOB 10/25 2 W /MOTOR 12.25 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 .1215 .0836 PIPE DATA DRILL STRING DC 8.0 2.875 .0080 .0542 DRILL RATE ft/hr CORRECTED "0" EXP. SHALE DENSITY g/cc EWR Res. NO. 7 DATE Mar 17 98 TIME 0001 P.B.U. NORTH SLOPE ALASKA 85 .79 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAULIC DATA PUMPS 1. SIZE inches CAPACITY gal/stk PUMP RATE stks/min FLOW RATE gal/min PRESSURE psi PO SURF / OS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT-VEL FT/MIN CASING: COND SURF DEPTH 110 2676 20.0" 13 3/8" 19.12 1 2. 41 5 .355 .1498 .0334 .0240 110 94 68 147 REMARKS AND RECOMMENDATIONS ID 1 600 6 X 12 4.22 2. 10 1 600 6 X 12 4.22 STATIC psi at _stk/min psi at ~tk/min ANN·VOL BBLS ftImi = sec/std 1 spe~ rsun ( DRILLING SERVICES LOGGING SYSTE"MS A ŒESSER NXJSTRES NC. COWPÞNf t DEPTH 2680 OPERATION CIRCULATE FOOTAGE 0 I OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 1 BACKGROUND CONNECTION TRIP · FLOWLINE TEMP AVG GAS (units) 10 MAX GAS (units) 10 APPI.JED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA AT DEPTH (feet) SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 385 3075 I FORMAllON PRESSURE DATA CASING BOTTOM HOLE PORE PRESSURE 1247 psi 9.0 ppg 1254 psi 9.0 ppg FRACTURE PRESSURE NA psi ppg 1810 psi 13.0 ppg ECD 1302 psi 9.4 ppg psi NA ppg -- TIME TYPE WEIGHT IN · FUNNEL VIS. PV/YP GELS pH " FIL T/CAKE API HP-HT .", Pm Pf/Mf .. CHLORIDES ppm CALCIUM ppm , OIL/WATER/SOLIDS DAILY/CUM. COST 50 degrees F MUD DATA 22:00 3-18-98 KCL POLY - IN PITS 9.3 45 1 0/1 5 3/4 8.4 7.4-1/32 13.0 o .1/.45 30000 80 0/3.3/95 LENGTH - FT. 2403 DP - CSG 5 X 1 3 3/8 , I DP - HOLE 5 X 1 2.25" - DC-CSG 8 X 1 3 3/8 DC - HOLE 8 X 1 2.25" 261 FIELD/BLOCK AREA STATE @2632 DS .26 DEG - AZ 333 30% COAL - 40% CLAY -30% SAND 2680 BIT NO. 1 TYPE MA-1 JSL IADC CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOTAGE 2570 AVG ft/hr 102 GRADE 2-2-E-1 HOLE DEV. .26 COST/FT 35 R PM 140 WOB 10/25 BIT DATA 2 05M W /MOTOR 12.25 1 5-1 5-1 5-1 0 DRILL RATE ft/hr CORRECTED "D' EXP. SHALE DENSITY glee EWR Res. NO. 8 DATE Mar1898 TIME 0001 P.B.U. NORTH SLOPE ALASKA 85 .79 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAULIC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 75 flOW RATE gal/min 637 PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1 247 1 21 .1215 .0867 .0836 PIPE DATA 173 CRIT -VEL FT/MIN 255 290 DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2664 ! OD-inches 5.0 5.0 8.0 20.0" 1 3 3/8" . lID-inches 4.276 3.0 2.875 19.12 1 2. 41 5 .I I CAP -bbls/ft .0178 .0087 .0080 .355 .1498 D I S P-bbls/ft .0075 .0181 .0542 .0334 .0240 '-~ LENGTH-ft 1949 454 261 110 2664 WEIGHT-Ibs/ft 19.5 49 147 94 68 'cII.' 2. ID 1 600 6X 12 4.22 75 1950 75/880 1 0/985 345 1060 365 45% - 3.1/IN2 psi at _stk/min psi at _stk/min ANN-VOL BBLS REMARKS AND RECOMMENDATIONS 1 MW 9.3+ GPM 650 JETS 3-13; 1-10 2500 PSI I COMPLETE NIPPLE UP. TEST BOP. M/U NEW BHA WITH 1.5 DEG MOTOR ON BIT NO.2. RIH. LAY DOWN 24 JOINTS DP. RIH. TAG UP ON FLOAT COLLAR AT 2578'. CIRCULATE AND DISPLACE HOLE WITH WATERED BACK MUD. PRESSURE TEST CASING TO 3040 PSI J FOR 30 MINUTES. WELL KILL DRILL - CIRCULATE. · I .~ ,~ I AOT JOHN PATTON ft/mi = sec/std 1 (' spe~~ :t-sun DRILLING SERVICES LOGGING SYSTEMS A [JESSER I\DUSTFES NC. C(;)W'/JN'{ r. DEPTH 3689 (3673lVD) OPERATION SHORT TRIP FOOT AGE 1009 1 OPERATOR BP EXPLORATION ' CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 L 0 C. S E C 1 9 - T1 2N - R 11 E LOGGING DATA 1 Ava MAX AT GAS GAS DEPTH (units) (units) (feet) BACKGROUND 125 1995 3585 CONNECTION TRIP NA 3689 - FLOWLINE TEMP 75 degrees F ."'. PORE PRESSURE FRACTURE PRESSURE 1 ECO TIME TYPE WEIGHT IN . FUNNEL VIS. PV/YP GELS pH . FILT/CAKEAPI HP-HT Pm Pf/Mf -. CHLORIDES ppm CALCIUM ppm OIL/WA TER/SOLlDS DAILY/CUM. COST SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM FIELD/BLOCK AREA STATE @3619.7 OS .16.1 DEG - AZ 6.73 . 30% CLAY - 50% SILTSTONE - 20% SAND 3690 585 4700 CASING 1247 psi 9.0 1731 psi 12.5 1302 psi 9.4 FORMATION PRESSURE DATA BOTTOM HOLE ppg 1662 psi 8.7 ppg ppg 2485 psi 13.0 ppg ppg 1796 psi 9.4 ppg MUD DATA 20:303-19-98 KCL POLY 9.3 43 1 2/1 6 7/13 8.3 6.8 - 1/32 BIT NO. 1 TYPE MA-1 JSL lADe CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOTAGE 2570 A VG ft/hr 102 GRADE 2-2-E-1 HOLE DEV. .26 COST/FT 35 R PM 1 40 WOB 10/25 Brr DATA 2 05M W IMOTOR 12.25 15-15-15-10 7.3 1009 138 INC 16.1 35 150 1 0/25 DRILL RATE ftJhr CORRECTED "0" EXP. SHALE DENSITY glee EWR Res. NO. 9 DATE Mar 19 98 TIME 0001 P.B.U. NORTH SLOPE ALASKA 125 1.01 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 725 PRESSURE psi PO SURF I OS psi ANN I BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 2. ID 1 600 6X 12 4.22 86 2100 75/735 20/1 270 390 1365 535 60% ·4.6/IN2 psi at _stk/min psi at _stk/min ANNULAR DATA LENGTH - FT. VOLUME BBLS/FT. VELOCITY FT/MIN CRIT-VEL FT/MIN ANN-VOL BBLS DP - CSG 5 X 1 3 3/8 2664 .1247 138 240 DP - HOLE 5 X 1 2.25" 765 .1215 142 240 DC-CSG 8 X 1 3 3/8 -'-.' DC - HOLE 8 X 1 2.25" 261 .0836 206 280 PIPE DATA .... DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2664 r OD-inches 5.0 5.0 8.0 20.0' 13 3/8" ID -inches 4.276 3.0 2.875 19.12 1 2.41 5 ':"- CAP-bbls/ft .0178 .0087 .0080 .355 .1498 DISP-bbls/ft .0075 .0181 .0542 .0334 .0240 l LENGTH-ft 2974 454 261 110 2664 ~ WEIGHT-Ibs/ft 19.5 49 147 94 68 ~.. 1 MW 9.3+ o .08/.48 25000 400 0/4.6/94 GPM JETS REMARKS AND RECOMMENDATIONS 3-13; 1-10 2500 PSI ft/mi 650 = sec/std DRILL OUT FLOAT COLLAR AND SHOE PLUS 10' OF NEW HOLE TO 2690'. DISPLACE HOLE WITH 9.3 PPG KCL POLY MUD. RUN LEAK OFF TEST. TEST YIELDED 12.5 PPG LEAK OFF. DRILL AHEAD WITH BIT NO.2. START ANGLE BUILD ABOUT 100' OUT OF CASING OCCASIONALLY I SLIDING TO ADJUST ANGLE AND DIRECTION. REDUCE PORE PRESSURE ESTIMATE FOR UGNU TO 8.7 PPG RELATIVE TO GAS READINGS IN ,_ THIS FORMATION. TWO SANDS DRILLED AT 3575-3600 & 3625-3675' CONTAINED HIGH GAS READINGS. MAX GAS FROM 3585' =1995 UNITS. HEAVY OIL SHOW NOTED IN LOWER SAND. DRILL TO 3689'. CBU FOR SHORT TRIP. WILL EVALUATE PORE PRESSURE ESTIMATE WITH TRIP I' GAS FROM BOTTOM. !ADT JOHN PATTON 1 I. DEPTH 4462 (4351 TVD) OPERATION DRILLING FOOT AGE 773 OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA · START DATE Marl098 1 I BACKGROUND CONNECTION . TRIP FLOWLINE TEMP 1 I AVG GAS (units) 200 MAX GAS (units) 4160 135 3689 degrees F 90 CASING PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 ECD 1330 psi 9.6 TIME l TYPE WEIGHT IN , FUNNEL VIS. PV /YP GELS pH I FIL T/CAKE API HP-HT Pm Pf/Mf ... CHLORIDES ppm CALCIUM ppm OIL/WA TER/SOLlDS DAILY/CUM. COST ~ MUD DATA 3-20-98 KCL POLY 9.5 44 1 3/26 1 0/1 9 8.2 8.0 - 2/32 .28/1.32 29000 LENGTH - FT. 2664 762 261 ~ DP HWDP . OD-inehes 5.0 5.0 . ID-inehes 4.276 3.0 Ii CAP-bbls/ft .0178 .0087 DISP-bbls/ft .0075 .0181 , I LENGTH-ft 2971 454 I WEIGHT-Ibs/ft 19.5 49 ,. iMW j 9.5 ( sperry-sun DRILLING SERVICES A ŒESSER NJUSlfES NC. COfo/PW{ (" LOGGING SYSTEMS APPLJED DRIWNG TECHNOLOOY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - RllE LOGGING DATA AT DEPTH (feet) 4095 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 709 5600 FORMA11ON PRESSURE DATA BOTTOM HOLE ppg 1991 psi 8.8 ppg p pg 2987 psi 13.2 p pg ppg 2172 psi 9.6 ppg FIELD/BLOCK AREA STATE (ã)4367.9 OS .34.2 DEG - AZ 8.24 30% CLAY - 40% SILTSTONE - 30% SAND 4440 BIT NO. 1 TYPE MA-l JSL lADe CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOT AGE 2570 A VG ft/hr 102 GRADE 2-2-E-1 HOLE DEV. .26 COST/FT 35 R PM 1 40 WOB 10/25 BIT DATA 2 05M W /MOTOR 12.25 15-15-15-10 18.4 1785 97 INC 34.2 35 155 1 0/25 DRILL RATE ft/hr CORRECTED "0" EXP. SHALE DENSITY glee EWR Res. NO. 10 DATE Mar 20 98 TIME 0001 P.B.U. NORTH SLOPE ALASKA 50 1.11 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. 10 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 725 PRESSURE psi PO SURF / OS psi ANN / BIT psi JET VELOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 138 .1215 142 CRIT -VEL FT/MIN 240 240 .0836 206 280 PIPE DATA DRILL STRING CASING: COND SURF DC DEPTH 110 2664 8.0 20.0" 1 3 3/8" 2.875 19.12 , 2.41 5 .0080 .355 .1498 .0542 .0334 .0240 261 110 2664 147 94 68 GPM 650 REMARKS AND RECOMMENDATIONS JETS 3-13; 1-10 2500 PSI ft/mi = 2. 10 1 600 6X 12 4.22 86 2100 75/735 20/1270 390 1365 ' 535 60% - 4.6/IN2 psi at _stk/min psi at _stk/min ANN-VOL BBLS sec/std MAX GAS FROM TRIP AT 3689 = 135. DRILL AHEAD WITH BIT NO.2. HIGH BACKGROUND READINGS RECORDED WHILE DRILLING THROUGH SANDS IN THE LOWER UGNU AND WEST SAK THAT CONTAINED GOOD OIL SHOWS. MAX GAS PAST 24 HRS = 4160 UNITS FROM 4095. RAISE >.1 I MUD WEIGHT TO 9.5 AROUND 3875. NO CONNECTION GAS RECORDED INDICATING ADEQUATE OVERBALANCE. CURRENT PORE PRESSURE t ESTIMATE IS 8.7 - 9.0 PPG. HOLE APPEARS TO BE IN GOOD SHAPE. DP - CSG 5 X 1 3 3/8 DP - HOLE 5 X 1 2.25" ] DC-CSG 8 X 1 3 3/8 DC - HOLE 8 X 1 2.25" ] IADT JOHN PATTON I. I. DEPTH 5205 (4952 TVD) OPERATION DRILLING FOOT AGE 743 I.' OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 [ BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG GAS (units) 150 200 760 MAX GAS (units) 1850 90 AT DEPTH (feet) 4480 5205 5176 degrees F ( sperry-sun DRILLING SERVICES A [HSSER NJUSlFES NC. CONPAN'f ( LOGGING SYSTEMS APPIJED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM FIELD/BLOCK AREA STATE @ 5104.3 DS 38.4 DEG 90% SILTSTONE -10% SANDSTONE 5160 845 6400 CASING PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 ECD 1343 psi 9.7 FORMATION PRESSURE DATA BOTTOM HOLE ppg 2318 psi 9.0 ppg ppg 3630 psi 14.1 ppg ppg 2498 psi 9.7 ppg TIME 'I' TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH FIL T/CAKE API HP-HT ,." P m Pf/Mf ,,,,. CHLORIDES ppm CALCIUM ppm 'II! OIL/WATER/SOLIDS DAILY/CUM. COST .~ ~ J > '1 ~i ~, ~~ ! '. ,..; i D P - CSG DP - HOLE DC-CSG ~ 'I DC - HOLE j I ... OD-inehes ¡ ID-inehes ..I CAP-bbls/ft D I S P -bbls/ft f LENGTH-ft WEIGHT-Ibs/ft , I MUD DATA 3-21 -98 KCL POLY 9.6 42 1 3/1 4 5/12 8.2 6.2 - 2/32 -13.6 o 1 .6/1 .1 0 23000 72 .1/92/6.6 5 X 1 3 3/8 5 X 1 2.25" 8X133/8 8 X 1 2.25" DP 5.0 4.276 .0178 .0075 4490 19.5 LENGTH - FT. 2664 2280 261 HWDP 5.0 3.0 .0087 .0181 454 49 BIT NO. 1 TYPE MA-1 JSL IADC CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOTAGE 2570 A VG ft/hr 102 GRADE 2-2-E-1 HOLE DEV. .26 COST/FT 35 R PM 140 WOB 10/25 err DATA 2 05M W IMOTOR 12.25 15-15-15-10 31.4 2525 80 INC 38.4 35 155 20/30 DRILL RATE ft/hr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. NO. 11 DATE Mar 21 98 TIME 0001 P.B.U. NORTH SLOPE ALASKA 45 1.20 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 725 PRESSURE psi PD SURF / DS psi ANN 1 BIT psi JET VELOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 ANNUlAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1 247 138 .1215 142 CRIT -VEL FT/MIN 210 210 .0836 206 240 PIPE DATA DRILL STRING CASING: COND SURF DC DEPTH 110 2664 8.0 20.0" 13 3/8" 2.875 19.12 1 2.41 5 .0080 .355 .1498 .0542 .0334 .0240 261 110 2664 147 94 68 2. I D 1 600 6 X 12 4.22 86 2400 75/1025 20/1 300 390 1410 555 55% - 4.7 IIN2 psi at _stk/min psi at _stk/min ANN-VOL BBLS j , ÆMARKSAND RECOMMENDATIONS MW 9.6 GPM 650 JETS 3-14; 1-10 2500 PSI ft/mi = I CONTINUE DRILLING WITH BIT NO.2 IN SILTSTONE FORMATION FROM 5000'. CONNECTION GAS READINGS AVERAGING 150 ABOVE I BACKGROUND IN THIS FORMATION. RAISE PORE PRESSURE ESTIMATE TO 9.0 RELATIVE TO GAS READINGS. DRILL TO 5176. CBU. SHORT TRIP 16 STANDS TO 3649. RIH. DRILL AHEAD. MAX GAS FROM TRIP = 760. ABUNDANT CLAY NOTED AT SHAKERS CIRCULATING 1 AFTER TRIP. HOLE UNLOADING WALL CAKE BUILD UP ON UPPER SANDS. CONNECTION GAS READINGS AVERAGING 50 UNITS ABOVE BACKGROUND AFTER TRIP. ~I' ADT JOHN PATTON sec/std t DEPTH 5939 (55~ TVD) OPERATION DRILLING FOOTAGE 729 OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 .. r" "\ -.. BACKGROUND , CONNECTION TRIP FLOWLINE TEMP PORE PRESSURE FRACTURE PRESSURE ECD TIME TYPE WEIGHT IN FUNNEL VIS. PV /YP GELS pH FIL T/CAKE API HP-HT Pm PfIMf CHLORIDES ppm CALCIUM ppm OIL/WA TERISOllDS ,j 'I DAIL Y /CUM. COST I II AVG GAS (units) 250 350 760 98 MAX GAS (units) 735 sperf -sun ( D~~f 8ERVI~ES LOGGING SYSTEMS A ~1tl:8NC. COWÞNf APPlIÐ DRlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA AT DEPTH (fe81) 5575 5918 5176 degrees F SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM NO.1? DATE Mar 22 98 TIME 00 01 FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA (;iJ 5573 DS ~3 DFG Al'? 7 60% SILTSTONE+SHALE ·10% SANDSTONE· 30% TUFF 5910 9Ø8 7300 CASING 1247 psi 9.0 1731 pai 12.5 1371 psi 9.9 FORMATION PRESSURE DATA BOTTOM HOLE ppg 2700 psi 9.4 ppg ppg 4310 psi 15.0 ppg ppg 2845 psi 9.9 ppg lIT DATA MUD DATA 3·22·98 KCL POLY 9.8 54 17/22 9/18 8.3 6.4· 2/32 13.6 o 0.0/1.10 28000 60 0190/8.5 ¡I ~ DP . CSG 5X133/8 :;'1 ~ DP - HOLE 5 X 12.25' , i DC-CSG 8X133/8 \1 'I - . DC - HOLE 8 X 12.25' ., 1 'OD-Inchea ID -Inchea ~ CAP-bbts/ft 'DISP.bbIS/ft ~ - LENGTH-ft WEIGHT-Ibs/ft ~- >. DP 5.0 4.276 .0178 .0075 5219 19.5 LENGTH· FT. 2664 3009 261 HWDP 5.0 3.0 .0087 .0181 454 49 BIT NO. 1 TYPE MA-1JSL IADC CODE SIZE 16.0 JETS 15-15-10 DEPTH OUT 2680 ROT HRS. 25.2 FOOTAGE 2570 AVG ftlhr 102 GRADE 2-2-E-1 HOLE DEV. .26 COSTIFT 35 RPM 140 WOB , 10/25 2 05M W /MOTOR 12.25 1,5-15-15-10 5939 48.2 3259 67.5 NA 38.3 35 155 20/35 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 138 .1215 .0836 PlÆ DATA DRILL STRING DC 8.0 2.875 .0080 .0542 261 147 142 206 DRILL RATE ftJhr 45 CORRECTED '0" EXP. 1.35 SHALE DENSITY glcc EWR Res. OPEN HOLE pal ppg pai ppg psi ppg HYDRAIJUC DATA 2. 101600 6X 12 4.22 86 ft ft ft PUMPS 1. 101600 SIZE Inches 6 X 12 CAPACITY gal/atk 4.22 PUMP RATE stks/mln 85 FLOW RATE gal/min 725 PRESSURE psi PD SURF I OS psi ANN / BIT psi JET VELOCITY ftJaec JET IMPACT Ibs BITHP HP RATIO / HP/IN2 REDUCED 1 RATE 2 2400 7511025 20/1300 390 1410 555 55% - 4.7 /IN2 pal at stktmln - psi at -,tklmln CRIT-VEl FTtMlN 210 ANN-VOL BBLS 210 240 CASING: COND DEPTH 110 20.0' 19.12 .355 .0334 110 94 SURF 2664 1 3 3/8' 12.415 .1498 .0240 2664 68 REMARKS AND RECOMMENDAllONS J MW 9.8 GÞM 650 JETS 3-14; 1-10 2500 PSI ftlml = sec/std I CONTINUE DR-ILlING WITH BIT NO.2. RAISE PORE PRESSURE ESTIMATE TO 9.2 IN LOWER SEABEE FORMATION RELATIVE TO RE~ITY TREND. CONNECTION GAS LOGGED AFTER DRILLING INTO TOROK FORMATION AVERAGING 100 - 150 UNITS OVER BACKGROUND. RAISE II ,PORE PRESSURE ESTIMATE TO 9.4·9.5 PPG AT 5750. CURRENT MUD WEIGHT AT 9.8 PPG. DRILL TO 5939. CIRCULATE AND CLEAN HOLE FOR TRIP TO CHANGE BIT. BACKGROUND GAS REDUCE TO 80 UNITS. POOH. I J ."ADT JOHN PATTON ~ I I DEPTH 6112 (5687 TVD) OPERATION DRILLING FOOT AGE 178 OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar1098 BACKGROUND CONNECTION TRIP FLOWLINE TEMP ..Jf PORE PRESSURE FRACTURE PRESSURE ECD .,;¡- , TIME TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH FIL T/CAKE API HP-HT ""¡ Pm j. Pf/Mf CHLORIDES ppm CALCIUM ppm ; lOlL/WATER/SOLIDS }- ~ DAILY/CUM. COST , ¡ j DP - CSG r~ I DP - HOLE '1 I ,} I :t I DC - HOLE I í OD-inches !. ID-inehes I CAP-bbls/ft ~ DISP-bbls/ft LENGTH·ft I WEIGHT-Ibs/ft AVG GAS (units) 150 200 1260 85 MUD DATA 3-23-98 KCL POLY 10.0 56 17/20 9/30 8.4 7.0- 2/32 14.0 .40 0.15/1.20 28500 112 0/90/8.4 5 X 1 3 3/8 5 X 1 2.25' 8 X 1 2.25" DP 5.0 4.276 .0178 .0075 5397 19.5 MAX GAS (units) 315 5939 degrees F CASING 1247 psi 9.0 1731 psi 12.5 1399 psi 10.1 LENGTH - FT. 2664 3427 261 HWDP 5.0 3.0 .0087 .0181 454 49 (' ( sperry-sun DRILLING SERVICES lOGGING SYSTEMS A ŒESSER NJUSTFES NC. CONf'ÞNY APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EilEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E lOGGING DATA AT DEPTH (feet) 5975 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1000 7550 FIELD/BLOCK AREA STATE NO. 13 DATE Mar 2398 TIME 00 01 P.B.U. NORTH SLOPE ALASKA (ã) 6040 DS 28.95 DEG AZ 18.6 60% SILTSTONE + SHALE - 10% SANDSTONE - 30% TUFF 6090 FORMA11ON PRESSURE DATA BOTTOM HOLE ppg 2987 psi 9.5 ppg ppg 4435 psi 15.0 ppg ppg 2987 psi 10.1 ppg BrT DATA BIT NO. TYPE IADC CODE SIZE JETS DEPTH OUT ROT HRS. 4.0 FOOTAGE 173 AVG ft/hr 43.2 GRADE HOLE DEV. 28 COST/FT 150 R PM 155 WOB 25/35 3 MFDSSHLL W /MOTOR 12.25 15-15-15-10 2 05M W /MOTOR 12.25 15-15-15-10 5939 48.2 3259 67.6 6-3-BT -E-I 38.3 35 155 20/35 DRill RATE ft/hr 35 CORRECTED "D" EXP. 1.32 SHALE DENSITY glee EWR Res. OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA 2. ID 1 600 6 X 12 4.22 86 2800 75/1330 35/1 360 390 1470 580 50% - 4.9 /IN2 psi at -=,tk/min psi at _stk/min ANN-VOL BBLS ~ANDRECOMMENDATIONS I MW 10.0 GPM 650 JETS 3-14; 1-10 2800 PSI ftlmi = sec/std , I POOH. GOOD TRIP ON WAY OUT. M/U NEW BHA ON BIT NO.3. RIH. SLIP LINE AT CASING SHOE. RIH. DRILL AHEAD. MAX GAS FROM TRIP , CAME FROM APPROXIMATELY 4000' FROM HYDROCARBON RICH SANDS. MAX GAS = 1260 UNITS. DUMPING MUD AT TIME OF PEAK TRIP GAS READING BY BYPASSING PARTIAL FLOW AT SHAKERS INHIBUTING ACTUAL PEAK READING. CURRENTLY DECREASING HOLE ANGLE AS PER _I WELL PLAN. CONNECTION GAS AVERAGING ABOUT 50 UNITS OVER BACKGROUND WITH 10.0 MUD WEIGHT. CURRENT PORE PRESSURE ( ESTlM,ATE IS 9.5 PPG. IADT JOHN PATTON ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 1 38 .1215 142 PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 725 PRESSURE psi PD SURF 1 DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT -VEL FT/MIN 260 260 .0836 206 305 PIPE DATA DRILL STRING CASING: COND SURF DC DEPTH 110 2664 8.0 20.0" 13 3/8" 2.875 19.12 1 2.41 5 .0080 .355 .1498 .0542 .0334 .0240 261 110 2664 147 94 68 1 t DEPTH ~195 (6238 TVD) OPERATION DRilLING FOOTAGE 593 _1_ OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 ( ( sper\ ~-sun OR~~~~ SERVICES LOGGING SYSTEMS A ~I~~ CCJJIt6Rt( APPUED DflWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOCo SEC 19 - T12N - R11E LeGGING DATA [ AVO MAX AT GAS GAS DEPTH (units) (units) (feel) ( BACKGROUND 200 615 6260 CONNECTION 350 6692 TRIP 1260 5939 FLOWLINE TEMP 98 degrees F . PORE PRESSURE FRACTURE PRESSURE ECD CASING 1247 psi 9.0 1731 psi 12.5 1437 psi 10.3 TIME , TYPE WEIGHT IN FUNNEL VIS. PV/YP .. GELS pH FIL T /CAKE API HP-HT MUD DATA 3-24-98 KCL POLY 10.2 53 1 5/19 11/40 8.3 6.4- 2/32 8.4 00 0.10/1.00 30000 80 0(90/8.4 Pm PI/Mf .. CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST :~..., DP . CSG 5X133/8 ,.. OP - HOLE 5 X 12.25" 1: ~r DC . HOLE 8 X 12.2& 1- OD-inches ¡ , . 10-inches "'-I CAP-bbls/ft OISP-bbls/ft ILENGTH.ft WEIGHT -Ibs/ft ,- I OP 5.0 4.276 .0178 .0075 5865 19.5 GPM 650 LENGTH - FT. 2664 3780 230 HWDP 5.0 3.0 .0087 .0181 607 49 JETS JOHN PATTON NO. 14 DATE' Mar 24 gs TIME 00 01 FIELD/BLOCK AREA STATE (;ð 6649.4 DS 17.22 DFG AZ ?S.7 80% SHALE - 1 0% SilTSTONE - 10% TUFF 6690 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP lAG OFF BOTTOM 1105 . 8150 FORMATION PRESSUFE DATA BOTTOM HOLE ppg 3146 psi 9.7 ppg ppg 5028 psi 15.5 ppg ppg 3341 pal 10.3 ppg Elf DATA BIT NO. 3 TYPE MFDSSHLl IADC CODE W IMOTOR SIZE 12.25 JETS 15-15-15-10 DEPTH OUT ROT HRS. 22.4 FOOTAGE 766 AVG ft/hr 34.3 GRADE HOLE DEV. 17 COST /FT 95 RPM 155 WOB 25/40 2 05M W ¡MOTOR 12.25 15-15-15-' 0 5939 48.2 3259 67.6 6-3-BT -E-I 38.3 35 155 20/35 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 139 .1215 .0836 PIÆ DATA DRILL STRING DC 8.0 2.875 .0080 .0542 230 147 143 208 DRILL RATE ft/hr CORRECTED "0" EXP. SHALE DENSITY glee EWR Rea. P.B.U. NORTH SLOPE ALASKA 35 1.38 OPEN HOLE psi ppg psi ppg psi ppg HYDRAULIC DATA 2. ID 1600 ex 12 4.22 86 PUMPS ,. 10 1600 SIZE inches 6 X 12 CAPACITY gal/atk 4.22 PUMP RATE atks/min 86 FLOW RATE gal/min 727 PRESSURE psi PO SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BITHP HP RATIO / HP/lN2 REDUCED 1 RATE 2 CRIT -VEL FT/MIN 245 245 295 CASING: COND DEPTH 110 20.0" 1 9.1 2 .355 .0334 110 94 FEMARKS AND RECOMMENDATIONS 3-14; 1-10 2800 PSI SURF 2664 1 3 3/8" 12.415 .1498 .0240 2684 88 ftlmi It It It 2850 75/1365 35/1375 392 1475 585 48% - 4.9 jlN2 psi at stk/min - psi at uk/mln - ANN-VOL BBlS = sec/std (MW 10.1 I CONTINUE DRILLING WITH BIT NO.3. SLOW PENETRATION RATES EXPERIENCED ON THIS BIT RUN AVERAGING ABOUT 35 FPH IN SHALE FORMATION. K5 MARKER LOGGED 6610-6615'. CURRENTLY DRILLING IN HRZ. CONNECTION GAS AVERAGING 150 UNITS ABOVE I BACKGROUND WITH 10.2 MUD WEIGHT. RAISE PORE PRESSURE ESTIMATE TO 9.7 PPG FOR THIS lONE. ADDING BRINE WATER AND I ~RESH MUD TO CONTROL LOW GRAVITY SOLIDS BUILD UP IN MUD. 11 IAQT I. [ DEPTH 6847 (6373 TVD) OPERATION TEST BOP FOOT AGE 142 ( OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 I BACKGROUND CONNECTION TRIP flOWLINE TEMP ..ì ~ PORE PRESSURE FRACTURE PRESSURE ECD TIME TYPE WEIGHT IN FUNNEL VIS. PV /YP GELS pH Fll T/CAKE API HP-HT ,~ Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOUDS DAilY/CUM. COST ,.1 " DP - CSG DP - HOLE ~ .- DC - HOLE OD-inehes ID-inehes CAP -bbls/ft D I S P -bbls/ft lENGTH-ft WEIGHT-Ibs/ft MW 10.2 AVG GAS (units) 200 350 1260 110 MUD DATA 3-25-98 KCL POLY 10.2 43 1 5/1 3 7/26 7.9 8.6- 2/32 16.4 00 0.00/1.10 29000 120 0/90/8.4 5 X 1 3 3/8 5 X 1 2.25" 8X12.25" DP 5.0 4.276 .0178 .0075 6010 19.5 GPM MAX GAS (units) 438 AT DEPTH (feet) 6820 6692 5939 degrees F CASING 1247 psi 9.0 1731 psi 12.5 1437 psi 10.3 LENGTH - FT. 2664 3953 230 HWDP 5.0 3.0 .0087 .0181 607 49 (' spe/a$-sun DRILLING SERVICES lCX7GING SYSTE'MS A ŒESSER N)lJS1ŒS NC. cotIf'ÞNi APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOCo SEC 19 - T12N - R11E LOGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES lAG DOWN DP LAG OFF BOTTOM FIELD/BLOCK AREA STATE @ 6649.4 OS 17.22DEG AZ 26.7 80% SHALE - 10% SILTSTONE - 10% TUFF 6840 1115 8250 DRILL RATE ft/hr CORRECTED '0' EXP. SHALE DENSITY glee EWR Res. NO. 15 DATE Mar 25 98 TIME 00 01 P.B.U. NORTH SLOPE ALASKA 45 1.22 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. 101600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 86 FLOW RATE gal/min 727 PRESSURE psi PD SURF / OS psi ANN / BIT psi JET VElOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT -VEL FT/MIN 245 245 295 DRilL STRING DC 8.0 2.875 .0080 .0542 230 147 CASING: COND DEPTH 110 20.0' 19.12 .355 .0334 110 94 SURF 2664 1 3 3/8" 12.415 .1498 .0240 2664 68 FORMATJON PRESSURE DATA BOTTOM HOLE p p 9 321 5 psi 9.7 P P 9 P pg 5236 psi 15.8 p pg ppg 3413 psi 10.3 ppg BIT DATA BIT NO. 3 TYPE MFDSSHlL IADC CODE W/MOTOR SIZE 12.25 JETS 15-15-15-10 DEPTH OUT 6847 ROT HRS. 26.8 FOOTAGE 908 AVG ft/hr 33.9 GRADE HOLE DEV. 17 COST/FT 88 R PM 1 55 WOB 25/40 4 MFDSSHCL 12.25 14-14-14-12 650 REMARKS AND RECOMMENDATIONS JETS 3-14; 1-10 2800 PSI ft/mi = 2. ID 1 600 6X 12 4.22 86 2850 75/1 365 35/1375 392 1475 585 48% - 4.9 /IN2 psi at _stk/min psi at ~tk/min ANN-VOL BBlS sec/std DRilL PAST K-1 MARKER. CBU AT 6847. POOH TO CHANGE BIT AND BHA TO PUT MWD CLOSE TO THE BIT FOR PICKING CORE POINT. M\U NEW BHA ON BIT NO.4. RIH TO SHOE. SET RTTS 45' BElOW RKB. PULL WEAR RING. SET TEST PLUG. TEST BOP. ANNULAR DATA VOLUME BBlS/FT. VELOCITY FT/MIN .1247 139 .1215 143 NOTE: ANTICIPATING 9.8-10.0 PPG PORE PRESSURE IN THE KUPARUK SANDS ASSUMING THAT THERE IS NOT ANY INJECTION PRESSURE PRESENT ON THIS lOCATION. ADT JOHN PATTON .0836 208 PIPE DATA 4H J J DEPTH 6925 (6447 TVD) OPERATION DRILLING FOOTAGE 78 sper¡~-sun ~ DRILLING SERVICES lOGGING SYSTEMS A (JÐSffi NJUSTFES NC. COfÆ'ÞNf JJ OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA I START DATE Mar 1098 1 BACKGROUND CONNECTION TRIP ~ FLOWLINE TEMP AVG GAS (units) 140 175 950 105 MAX GAS (units) 200 6847 degrees F CASING 1 PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 ECD 1437 psi 10.3 ,- ITlME 1_ TYPE WEIGHT IN . 1 FUNNEL VIS. PV/YP ..,-' GELS pH 'I FIL TlCAKE API HP-HT .' Pm ) Pf/Mf - 'I CHLORIDES ppm CALCIUM ppm OIL/WA TER/SOLlDS DAILY/CUM. COST ì "f I J: I , ~;.l I DP - CSG DP - HOLE DC - HOLE ~~ I ] OD-inehes ID-inehes , I CAP-bbls/ft DISP-bbls/ft LENGTH-ft " . WEIGHT-Ibs/ft J I MUD DATA 3-26-98 KCL POLY 10.2 52 1 6/1 2 6/25 8.0 7.0- 2/32 14.0 o 0.1 0/1 .80 31000 80 0/90/8.3 5X133/8 5 X 1 2.25' 8 X 1 2.25" DP 5.0 4.276 .0178 .0075 6117 19.5 LENGTH - FT. 2664 4091 APPIJED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA AT DEPTH (feet) 6875 FIELD/BLOCK AREA STATE NO. 16 DATE Mar 26 98 TIME 0001 P.B.U. NORTH SLOPE ALASKA @ 6850.3 DS 17.87 DEG AZ 39.1 70% SHALE - 1 0% SILTSTONE - 10% TUFF - 10% SAND 6900 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1145 8450 FORMA11ON PRESSURE DATA BOTTOM HOLE ppg 3285 psi 9.7 ppg ppg 5297 psi 15.8 ppg ppg 3453 psi 10.3 ppg DRILL RATE ft/hr 22 CORRECTED 'D' EXP. 1.45 SHALE DENSITY glee EWR Res. OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 719 PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 136 BIT DATA BIT NO. 3 TYPE MFDSSHLL lADe CODE W /MOTOR SIZE 12.25 JETS 15-15-15-10 DEPTH OUT 6847 ROT HRS. 26.8 FOOTAGE 908 A VG ft/hr 33.9 GRADE 2-3-WT-A-E-1 HOLE DEV. 17 COST /FT 88 R PM 1 55 WOB 25/40 .1215 4 MFDSSHCL 12.25 14-14-14-12 2.8 78 27.9 17 365 100 35/40 141 CRIT-VEL FT/MIN 170 170 .0836 205 215 PIPE DATA DRILL STRING CASING: COND SURF DC DEPTH 110 2664 8.0 20.0" 1 3 3/8" 2.875 19.12 1 2.41 5 .0080 .355 .1498 .0542 .0334 .0240 170 110 2664 147 94 68 2. ID 1 600 6 X 12 4.22 85 3150 75/1515 25/1 535 410 1560 645 49% - 5.5 /IN2 psi at _stkJmin psi at ~tk/min ANN-VOL BBLS REMARKS AND RECOMMENDATIONS MW 10.2 GPM 650 JETS 3-14; 1-10 2800 PSI ft/mi = sec/std II. - .~ I REPLACE SEAL IN BLIND RAMS. TEST BOP. CBU AT SHOE. RIH. CIRCULATE AT 3900. RIH TO 5230. CIRCULATE AND REAM TIGHT SPOT I 5240-5333. RIH TO 6845. WASH&REAM TO BOTTOM. MAX GAS = 950. SLOUGHING SHALE + CLAY NOTED ON BOTTOMS UP. DRILL AHEAD FOR CORE POINT. SLOWER ROP LOGGED BELOW 6910 AFTER PENETRATING SIDERITE STRINGER. I' I ..,' IADT 170 HWDP 5.0 3.0 .0087 .0181 638 49 JOHN PATTON 1 f DEPTH 7œ4.6 (6~"~ TVD) OPERATION TRIP FOOTAGE 109 T ' OPERATOR BP EXPLORATION 1 CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 , ( spe~,-sun ' DRILLING SERVICE' lOGGING SYSTEMS A UtMI::H ~Itts IIIC. CØirN« APPlED DFlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19· T12N - R11E '.. AVG MAX AT GAS GAS DEPTH (units) (unita) (feet) BACKGROUND 80 110 6973 CONNECTION 105 7003 110. TRIP NA 7035 FLOWLINE TEMP 105 degreea F CASING PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 E C D 1 437 P ai 1 0.3 MUD DATA TIME 1'. TYPE WEIGHT IN FUNNEL VIS. PV/YP I,. :~LS FILT/CAKE API HP-HT 3·27 ·98 KCL POLY 10.2 45 1 4/1 6 316 8.3 4.6- 1/32 11.6 o 0.1/.60 34000 80 019018.1 r ~;MI CHLORIDES ppm CALCIUM ppm I,,' OIL/WATERISOLlDS : DAilY/CUM. COST · I ,- , í : DP - CSG 5X133/8 lENGTH· FT. 2664 ! - I OP . HOLE 5X12.25' 4200 I ' : I ¡ f¡ l , - DC . HOLE 8 X 12.25" 170 JOHN PATTON UJGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES lAG DOWN DP LAG OFF BOTTOM NO. 17 DATE Mar 2798 TIME 00 01 FIELD/BLOCK AREA STATE fR¡ 6850.3 DS 17.87 DFG ð7 39.1 50" SHALE - 401Jf. SILTSTONE· 101Jf. TUFF 7030 1155 8500 RFMATION PfESSURE DATA BOTTOM HOLE ppg 3339 psi 9.8 ppg ppg 5383 pai 15.8 ppg ppg 3509 pai 10.3 ppg BIT DATA BIT NO. 5 TYPE ARC 325C3 IADC CODE CORE NO.1 SIZE 8.5 JETS TFA: 1.10 DEPTH OUT ROT HRS. FOOTAGE AVG ftlhr GRADE HOLE DEV. COST 1FT RPM WOB 4 MFDSSHCL 12.25 14-14-14-12 7034 9.0 188 20.9 1 -2-WT -O-E·I 11 350 90 35/40 ANNlI..AR DATA VOLUME BBlS/FT. VELOCITY FT/MIN .1247 136 .1215 141 .0836 205 PIPE DATA CASING: DEPTH DRILL RATE ftlhr CORRECTED "D" EXP. SHALE DENSITY :fee EWR Re.. P.B.U. NORTH SLOPE ALASKA 20 1.48 OPEN HOLE pal ppg pai ppg pal ppg HYDRAULIC DATA 2. 101600 6X 12 4.22 85 PUMPS ,. 10 1600 SIZE inches 6 X 12 CAPACITY gal/atk 4.22 PUMP RATE atka/min 85 FLOW RATE gal/min 719 PRESSURE psi PO SURF I OS pal ANN I BIT psi JET VELOCITY ftJaec JET IMPACT Iba BIT HP HP RATIO I HPIIN2 REDUCED 1 RATE 2 CAIT-VEl FTIMIN 170 170 215 COND 110 20.0" 19.12 .355 .0334 110 94 SURF 2664 1 3 3/8" 12.415 .1498 .0240 2664 68 : I DRILL STRINQ ·IIIOD-inch.. 5.:P 5~oWDP a.:ç · ID·inches 4.276 3.0 2.875 , 1 CAP-bbls/ft .0178 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 IllENGTH-ft 6226 638 170 · I WEIGHT-Ibs/ft 19.5 49 147 REMARKS AND RECOMMENDATIONS II MW _ 10.2 GPM 650 JËTS 3-14; 1·10 2800 PSI 1 DRILL TO 7034 - CORE POINT FOR THE KUPARUK C SAND. CBU. DISPLACE HOLE WITH FRESH KCl POLY FLUID. liON 8.5' ÇORE BIT. MIU NEW BAA RIH. Ç'RÇULATE AND FILL PIPE AT SHOE. RIH. -I " ~ADT ftImi ft: ft: It 3150 75/'51 5 25/1 535 410 1580 645 49CJ6 - 5.5 IIN2 pal at Itk/mln - psi at stk/mln - ANN·VOl BBlS POOH. M\U 90' CORE BARREL = sec/std I (. DEPTH 1995 (tMn 0 TVO) OPERATION tRIP FOOTAGE ?9 [OPERATOR BP EXPLORATION . CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 I. , ( 8pei~ 7'-SUn DRILLING S~RVlCES lOGGING SYSTEMS A Uöa:f1 tdJb.tts He. carNff APPt.IÐ DRlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LeGGING DATA AVG MAX AT GAS GAS DEPTH (units) (units) (feet) BACKGROUND 80 233 1080 CONNECTION TRIP 268 1034 FLOWLINE TEMP 90 degrees F I. ] CASING 1241 psi 9.0 1131 psi 12.5 1431 psi _10.3 PORE PRESSURE FRACTURE PRESSURE J ECD MUD DATA TIME I TYPE WEIGHT IN . FUNNEL VIS. PV fYP 1 GELS pH FllT/CAKE API HP-HT 3-29-98 KCL POLY 10.2 46 14/11 3/8 8.4 5. 2- 1132 11.6 .05 .10/.55 32000 80 0/91/7.2 I Pm pr/Mf . CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST ~, ,. DP - CSG OP - HOLE LENGTH - FT. 2664 5X133/8 5 X 12.25' 4221 1~ DC - HOLE 8X12.25· 210 j I OD-Inches lo-inches , 'CAP-bbls/h DISP-bbls/ft 'JILENGTH-ft ., ! WEIGHT -Ibs/h I DP 5.0 4.216 .0178 .0075 6247 19.5 HWDP 5.0 3.0 .0087 .0181 638 49 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1150 8500 FIELD/BLOCK AREA STATE @ 6850.3 OS 17.81 OFG A7 39.1 30% SHALE - 40% SILTSTONE - 30% SAND 1090 FORMATION PfESSUÆ DATA BOTTOM HOLE ppg 3368 psi 9.8 ppg ppg 5430 psi 15.8 ppg ppg 3540 psi 10.3 ppg BIT DATA BIT NO. RR 4 TYPE MFDSSHCL IADC CODE W /MOTOR SIZE 12.25 JETS 15-15-15-12 DEPTH OUT ROT HRS. FOOT AGE AVG ftlhr GRADE HOLE DEV. COST /FT RPM WOB RR 5 ARC 325C3 CORE NO.2 8.5 TFA:1.1 7095 5.8 29 5.0 2-3-CT -S-X-I 16 NA 95/1 00 5/10 DRILL RATE ftlhr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. NO. 19 DATE Mar 29 98 TIME 00 01 P.B.U. NORTH SLOPE ALASKA 1 _ 5 (CORING) 1.68 OPEN HOLE pai ppg pai p pg psi ppg HYDIWJUC DATA 2. ID 1600 6X 12 4.22 PUMPS 1. ID 1600 SIZE Inches 6 X 12 CAPACITY gal/atk 4.22 PUMP RATE stka/min 117 FLOW RATE gal/mln 493 PRESSURE psi PO SURF I DS psi ANN I BIT psi JET VELOCITY ftIsec JET IMPACT Ibs BIT HP HP RATIO / HP/lN2 REDUCED 1 RATE 2 CAIT -VEL FT/MIN 185 185 225 DRilL STRING DC 6.75 2.S75 .OOSO .0362 210 93 CASING: COND DEPTH 110 20.0' 19.12 .355 .0334 110 94 SURF 2664 1 3 3/S' 12.415 .1498 .0240 2664 68 ft ft ft 1500 80/845 201575 252 665 185 38% - 1. 4IIN2 pal at stk/mln - psi at -,tk/mln ANN-VOL BBLS ÆMAAKS AND ÆCOMMENDATIONS 11 ,MW 10.2 GPM 650 JETS 3-14; 1-12 3000 PSI ftImi = sec/std I START CORE NO.2 AT 7066. MAX GAS FROM TRIP am 253. CORE TO 1095. POOH. LAY DOWN CORE. RECOVER 29' OF CORE. MN NEW BHA I' ON RR BIT 4. RUN IN HOLE. REAM THROUGH CORED SECTION OF THE HOLE. I II I ADT JOþ-iN PATTON ANNULAR DATA VOLUME BBlSIFT. VELOCITY FT/MIN .1247 94 .1215 97 .0622 140 PIÆ DATA I [ DEPTH 7476 (6973 TVD) OPERATION CIRCULATE FOOTAGE 381 í OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA ST ART DATE Mar 1098 BACKGROUND CONNECTION TRIP , FLOWLINE TEMP _í PORE PRESSURE FRACTURE PRESSURE _~ ECD TIME TYPE WEIGHT IN FUNNEL VIS. PV/yP , GELS I pH / FILT/CAKE API HP-HT Pm : Pf/Mf ,_ CHLORIDES ppm ., I CALCIUM ppm - ,Oil/WATER/SOLIDS . , DAILY/CUM. COST , ~~ I 1 ,! ~ -XI t "\ " I ~ DP - CSG DP - HOLE DC - HOLE jl OD-inches riD-inches 1_ CAP-bbls/ft · I DISP-bbls/ft J LENGTH-ft . WEIGHT-Ibs/ft. MW 10.2 AVG GAS (units) 100 125 347 115 MAX GAS (units) 637 AT DEPTH (feet) 7140 7446 7095 degrees F CASING 1247 psi 9.0 1731 psi 12.5 1437 psi 10.3 MUD DATA 3-30-98 KCl POLY 10.2 54 23/28 11/27 7.5 3.6- 1/32 9.2 o .0/.90 34000 128 0/89/9.2 5 X 1 3 3/8 5 X 1 2.25" 8 X 1 2.25' DP 5.0 4.276 .0178 .0075 6828 19.5 GPM lENGTH - FT. 2664 4602 210 HWDP 5.0 3.0 .0087 .0181 638 49 , ( spen", -sun DRILLING SERVICES lCk3GING SYSTE"MS A rÆSS:H NJUS1ŒS NC. COWÞNf APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 L 0 C. S E C 1 9 - T1 2N - R 11 E lOGGING DATA SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES lAG DOWN DP LAG OFF BOTTOM NO. 20 DATE Mar 30 98 TIME 0001 FIELD/BLOCK AREA STATE (ii) 7409.4 OS 20.7 DE G AZ 58.6 20% SHALE - 50% SILTSTONE - 20% SAND 7460 1240 9250 FORMATION PRESSURE DATA BOTTOM HOLE ppg 3554 psi 9.8 ppg p pg 5765 psi 15.8 p pg ppg 3735 psi 10.3 ppg BIT DATA BIT NO. RR 4 TYPE MFDSSHCL lADe CODE WIMOTOR SIZE 12.25 JETS 15-15-15-12 DEPTH OUT 7476 ROT HRS. 12.0 +3.1 RM FOOT AGE 381 AVG ft/hr 31.8 GRADE NA HOLE DEV. 20 COST/FT 150 RPM 165 WOB 30/40 RR 5 ARC 325C3 CORE NO.2 8.5 TF A: 1.1 7095 5.8 29 5.0 2-3-CT-S-X-1 16 NA 95/1 00 5110 DRILL RATE ft/hr CORRECTED '0' EXP. SHALE DENSITY glee EWR Res. P.B.U. NORTH SLOPE ALASKA 30 1.43 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HVDRAUUC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 725 PRESSURE psi PD SURF I DS psi ANN I BIT psi JET VElOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO 1 HP/IN2 REDUCED 1 RATE 2 CRIT -VEL FT/MIN 320 320 375 DRILL STRING DC 6.75 2.875 .0080 .0362 210 93 CASING: COND DEPTH 110 20.0" 19.12 .355 .0334 110 94 SURF 2664 13 3/8" 1 2.41 5 .1498 .0240 2664 68 2. ID 1 600 6 X 12 4.22 85 3000 75/1620 55/1 250 370 1415 525 43% - 4.5 IIN2 psi at _stk/min psi at _stk/min ANN-VOL BBlS sec/std I REAM TO BOTTOM. MAX GAS FROM TRIP = 347. DRILL AHEAD WITH RR BIT 3. BASE OF KUPARUK "A" AT 7330. DRill TO 7476 OCCASIONALLY TO CORRECT THE ANGLE AND DIRECTION AS PER WELL PLAN. CIRCULATE AND CONDITION THE HOLE PRIOR TO TRIPPING OUT TO RUN E-LOGS. Î -,ADT ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 138 .1215 142 .0622 206 PIPE DATA 650 REMARKS AND RECOMMENDATIONS JETS 3-14; 1-12 3000 PSI JOHN PATTON ft/mi = I spe~' _ -sun ( DRILLING SERVICES lOGGING SYSTEMS A [JÐìSER NJUSlRES NC. CONP/W'f NO. ::>1 DATE Mar 31 98 TIME 00 01 DEPTH 7476 (6973 TVD) I. OPERATION E -LOG FOOTAGE 0 APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEe 19 - T12N - R11E P.B.U. NORTH SLOPE ALASKA FIELD/BLOCK AREA STATE OPERATOR BP EXPLORATION "I.' CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 [ lOGGING DATA MAX GAS (units) AT DEPTH (feet) AVG GAS (units) 45 @) 7409.4 DS 20.7 DEG AZ 58.6 20% SHALE - 50% SILTSTONE - 20% SAND 7460 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM DRILL RATE ft/hr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. 30 1.43 BACKGROUND CONNECTION TRIP FLOWLINE TEMP 1240 9250 7095 degrees F 347 115 FORMATJON PRESSURE DATA BOTTOM HOLE ppg 3554 psi 9.8 ppg ppg 5765 psi 15.8 ppg ppg 3735 psi 10.3 ppg BIT DATA I CASING PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 ECD 1437 psi 10.3 MUD DATA TIME 3-31 -98 TYPE KCL POLY WEIGHT IN 10.2 FUNNEL VIS. 57 PV /yP 1 9/1 7 GELS 7/17 pH 7.5 FIL T/CAKE API 3.8- 1/32 HP-HT 10.4 Pm 0 Pf/Mf .0/.50 CHLORIDES ppm 28000 CALCIUM ppm 120 OIL/WATER/SOLIDS 1.0/89/8.5 DAILY/CUM. COST ~ OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA 2. ID 1600 6 X 12 4.22 85 RR 5 ARC 325C3 CORE NO.2 8.5 TFA: 1.1 7095 5.8 29 5.0 2-'3-CT -S-X-I 16 NA 95/1 00 5/10 BIT NO. RR 4 TYPE MFDSSHCL IADC CODE W IMOTOR SIZE 12.25 JETS 15-15-15-12 DEPTH OUT 7476 ROT HRS. 12.0 +3.1 RM FOOTAGE 381 AVG ft/hr 31.8 GRADE 3-5-WT-A3-E HOLE DEV. 20 COST/FT 150 R PM 1 65 WOB 30/40 PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 725 PRESSURE psi PD SURF I DS psi ANN I BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO I HP/IN2 REDUCED 1 RATE 2 3000 75/1620 55/1250 370 1415 525 43% - 4.5 IIN2 psi at _stk/min psi at _stk/min ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1 247 1 38 ANN-VOL BBLS CRIT -VEL FTIMIN 320 LENGTH - FT. 2664 DP - CSG 5X133/8 .. J DP - HOLE 5 X 1 2.25' DC - HOLE 8 X 1 2.25' 142 320 .1215 4602 .0622 206 375 PIPE DATA DRILL STRING CASING: COND SURF DC DEPTH 110 2664 6.75 20.0' 13 3/8' 2.875 19.12 12.41 5 .0080 .355 .1498 .0362 .0334 .0240 210 110 2664 93 94 68 210 ... IOD-inches riD-inches .. CAP-bbls/ft IDISP-bbIS/ft LENGTH-ft I. WEIGHT-Ibs/ft DP 5.0 4.276 .0178 .0075 6828 19.5 HWDP 5.0 3.0 .0087 .0181 638 49 ~ANDREOOMMENDATIONS :,' MW 10.2 GPM 650 JETS 3-14; 1-12 3000 PSI ft/mi = sec/std ¡ I SPOT BARO-TROL/MINERAL OIL PILL ON BOTTOM FOR SHALE CONTROL. POOH. RUN ELECTRIC LOGS. TOOLS UNABLE TO GET PAST 5300'. LOG UPPER SECTION OF HOLE. III ¡I.ADT JOHN PATTON I I DEPTH 7476 (6973 TVO) OPERATION L/D TOOLS FOOTAGE 0 spe#:." -sun (' DRILLING SERVICES lOGGING SYSTE'MS A ŒESSER NJUSTFES NC. CONPN« OPERATOR BP EXPLORATION [. CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 APPUED DRIWNG TECHNOLOGY MORNING REPORT WEll NAME NORTHWEST EilEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E L~ING DATA [ AVG MAX AT GAS GAS DEPTH (units) (units) (feel) BACKGROUND 0 [ CONNECTION TRIP 347 7095 FLOWLINE TEMP 115 degrees F PORE PRESSURE FRACTURE PRESSURE ECD TIME TYPE WEIGHT IN FUNNEL VIS. PV {YP _I' GELS pH FIL T/CAKE API HP-HT Pm I Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST n, I D P - CSG " I ...,.. :'. ,~1 DP - HOLE '-"I DC - HOLE ..). 'OD-inehes liD-inches ,. CAP -bbls/ft I DISP-bbls/ft J LENGTH-ft " WEIGHT-Ibs/ft I MUD DATA 4-1-98 KCl POLY 10.2 56 20/1 8 8/22 7.7 3.8- 1/32 10.6 o .0/.80 32000 140 1.0/88/9.3 5X133/8 5 X,12.25" 8 X 12.25" DP 5.0 4.276 .0178 .0075 6828 19.5 CASING 1247 psi 9.0 1731 psi 12.5 1437 psi 10.3 LENGTH - FT. 2664 4602 210 HWDP 5.0 3.0 .0087 .0181 638 49 NO. 22 DATE Apr 1 98 TIME 00 01 FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA 1240 9250 FORMATION PRESSURE DATA BOTTOM HOLE ppg 3554 psi 9.8 ppg ppg 5765 psi 15.8 ppg ppg 3735 psi 10.3 ppg BrT DATA (á) 7409.4 DS 20.7 DEG AZ 58.6 20% SHALE - 50% SILTSTONE - 20% SAND 7460 1 2.25" HOLE OPEN 12.25 DRILL RATE ft/hr CORRECTED "D" EXP. SHALE DENSITY glee EWR Res. 30 1.43 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM BIT NO. RR 4 TYPE MFDSSHCL IADC CODE W /MOTOR SIZE 12.25 JETS 15-15-15-12 DEPTH OUT 7476 ROT HRS. 12.0 +3.1 RM FOOTAGE 381 AVG ft/hr 31.8 GRADE 3-5-WT-A3-E HOLE DEV. 20 COST /FT 150 R PM 1 65 WOB 30/40 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. SIZE inches CAPACITY gal/stk PUMP RATE stks/min flOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/see JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 ID 1 600 6 X 12 4.22 2. I D 1 600 6X 12 4.22 STATIC psi at ~tk/min psi at _stk/min ANNULAR DATA VOLUME BBLS/FT. VELOCITY FTlMIN .1247 CRIT-VEL FT/MIN 320 ANN-VOL BBLS 320 375 CASING: COND SURF DEPTH 110 2664 20.0' 1 3 3/8" 19.12 1 2.41 5 .355 .1498 .0334 .0240 110 2664 94 68 ~MSANDRECOMMENDATIONS J MW 10.2 GPM650 JETS 3-15; 1-12 2500 PSI ftlmi = , ". RUN ELECTRIC lOGS ON UPPER SECTION OF HOLE. RIH WITH DRILL PIPE CONVEYED LOGS. COULD NOT GET PAST 5300+/-. LID SCHLUMBERGER TOOLS. PREPARING TO RIH WITH HOLE OPENER TO CONDITION THE HOLE FOR LOGS. II II ,ADT JOHN PATTON .1215 .0622 PIPE DATA DR I LL STRING DC 6.75 2.875 .0080 .0362 210 93 sec/std POOH. I. I. DEPTH 7476 (6973 TVD) OPERATION REAMING FOOTAGE 0 OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA '. START DATE Mar 10 98 spe{, rSun DRILLING SERVICES LCX3GING SYSTE'MS A [J£SSER NJUSTFES NC. CONPÞNf APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E lOGGING DATA [ AVG MAX AT GAS GAS DEPTH (units) (units) (feet) BACKGROUND 75 610 @ TRIP CONNECTION TRIP 610 7095 ~ FLOWLINE TEMP 95 degrees F PORE PRESSURE FRACTURE PRESSURE ECD TIME . TYPE WEIGHT IN I FUNNEL VIS. PV NP GELS pH FILT/CAKE API HP-HT Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST D P - CSG DP - HOLE l' ,> I ;~t I DC _ HOLE I., J 10D-inehes ID-inehes . CAP·bbls/ft IDISP-bbIS/ft J LENGTH-ft ' WEIGHT-Ibs/ft I MUD DATA 4-2-98 KCL POLY 10.2 63 23/24 9/26 8.6 3.6- 1/32 8.4 .25 , .0/1.0 32000 180 2.0/87/9.3 5 X 1 3 3/8 5 X 12.25' 8 X 1 2.25" DP 5.0 4.276 .0178 .0075 6661 19.5 CASING 1247 psi 9.0 1731 psi 12.5 1437 psi 10.3 LENGTH - FT. 2664 4635 177 HWDP 5.0 3.0 .0087 .0181 638 49 ( NO. 23 DATE Apr 298 TIME 0001 FIELD/BLOCK AREA STATE @) 7409.4 DS 20.7 DEG AZ 58.6 , 20% SHALE - 50% SILTSTONE - 20% SAND 7460 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1240 9250 FORMATION PRESSURE DATA BOTTOM HOLE ppg 3554 psi 9.8 ppg ppg 5765 psi 15.8 ppg ppg 3735 psi 10.3 ppg BIT DATA BIT NO. RR 4 TYPE MFDSSHCL IADC CODE W /MOTOR SIZE 12.25 JETS 15-15-15-12 DEPTH OUT 7476 ROT HRS. 12.0 +3.1 RM FOOTAGE 381 AVG ft/hr 31.8 GRADE 3-5-WT-A3-E HOLE DEV. 20 COST/FT 150 R PM 1 65 WOB 30/40 12.25' HOLE OPEN 12.25 DRILL RATE ft/hr CORRECTED '0' EXP. SHALE DENSITY g/ec EWR Res. P.B.U. NORTH SLOPE ALASKA 30 1.43 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 700 PRESSURE psi PD SURF / OS psi ANN / BIT psi JET VELOCITY ft/see JET IMPACT Ibs BITHP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT-VEL FT/MIN 285 285 340 DRILL STRING DC 6.75 2.875 .0080 .0362 177 93 CASING: CO NO DEPTH 11 0 20.0" 19.12 .355 .0334 110 94 SURF 2664 1 3 3/8" 12.415 .1498 .0240 2664 68 2. ID 1 600 6 X 12 4.22 80 2250 75/1500 50/630 psi at _stk/min psi at _stk/min ANN-VOL BBLS ~ANDREOOMMENDATIONS I MW 10.2 GPM 650 JETS 3-15; 1-12 2500 PSI ftlmi = sec/std I RIH WITH 12.25' BULL NOSE HOLE OPENER TO 5237. REAM THROUGH TIGHT SECTION OF THE HOLE. REAMER TAKING WEIGHT ON HARD SPOTS AT 5530-5545. 5680-5690. 6113-6143. LAY DOWN 12 JOINTS. REAM FROM 6163-6253. RIH TO 7218. REAM TO BOTTOM. II I tDT JOHN PATTON ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 133 .1215 137 .0622 199 PIPE DATA t I. DEPTH 7476 (6973 TVD) OPERATION E-LOG FOOTAGE 0 I OPERATOR BP EXPLORATION I CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 [ BACKGROUND CONNECTION TRIP FLOWLINE TEMP ..iF PORE PRESSURE FRACTURE PRESSURE 1 ECD TIME TYPE WEIGHT IN . FUNNEL VIS. PVfYP -(' GELS pH FIL T/CAKE API HP-HT oJ Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WA TER/SOLlDS DAILY/CUM. COST DP - CSG DP - HOLE .,0' DC - HOLE .J OD-inehes ID-inehes CAP-bbls/ft DISP-bbls/ft LENGTH-ft WEIGHT-Ibs/ft ~ I , MW 10.2 AVG GAS (units) o 610 95 MUD DATA 4-2-98 KCL POLY 10.2 60 21/24 1 0/29 8.9 3.8- 1/32 8.4 .15 .05/1.2 30000 100 1.0/89/8.4 5X133/8 5 X 1 2.25' 8X12.25' DP 5.0 4.276 .0178 .0075 6661 19.5 GPM 650 MAX AT GAS DEPTH (units) (feet) 7476 degrees F CASING 1247 psi 9.0 1731 psi 12.5 1437 psi 10.3 LENGTH - FT. 2664 4635 177 HWDP 5.0 3.0 .0087 .0181 638 49 ( Spe~Y-SUn DRILLING SERVICES LOGGING SYSTEMS A I:HSSEß NJUSlfES NC. COWPÞH{ APPUED DRIWNG TECHNOlOOY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E lOGGING DATA NO. 24 DATE Apr 3 98 TIME 0001 FIELD/BLOCK AREA STATE @ 7409.4 DS 20.7 DEG AZ 58.6 20% SHALE - 50% SILTSTONE - 20% SAND 7460 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1240 9250 DRILL RATE ft/hr CORRECTED 'D' EXP. SHALE DENSITY glee EWR Res. P.B.U. NORTH SLOPE ALASKA 30 1.43 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA 2. I D 1 600 6 X 12 4.22 80 PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 85 FLOW RATE gal/min 700 PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/see JET IMPACT Ibs BITHP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT-VEL FT/MIN 285 285 340 DRill STRING DC 6.75 2.875 .0080 .0362 177 93 CASING: CO ND DEPTH 110 20.0' 19.12 .355 .0334 110 94 SURF 2664 13 3/8' 12.415 .1498 .0240 2664 68 FORMAllON PRESSURE DATA BOTTOM HOLE ppg 3554 psi 9.8 ppg ppg 5765 psi 15.8 ppg ppg 3735 psi 10.3 ppg 8fT DATA BIT NO. RR 4 TYPE MFDSSHCL IADC CODE WIMOTOR SIZE 12.25 JETS 15-15-15-12 DEPTH OUT 7476 ROT HRS. 12.0 +3.1 RM FOOTAGE 381 AVG ft/hr 31.8 GRADE 3-5-WT-A3-E HOLE DEV. 20 COSTIFT 150 R PM 165 WOB 30/40 1 2.25' HOLE OPEN 12.25 7475 REMARKS AND RECOMMENDATIONS JETS 3-15; 1-12 2500 PSI JOHN PATTON ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 133 .1215 137 .0622 199 ft/mi = SPOT STICKLESS PILL sec/std --I REAM TO BOTTOM FROM 7218. CIRCULATE AND CONDITION THE HOLE. SPOT BARO-TROL PILL POH TO 5250. I . !BEADS). POOH. RIU SCHLUMBERGER. RUN ELECTRIC LOGS. FIRST LOG RUN WENT TO BOTTOM. , I - I ADT PIPE DATA 2250 75/1500 50/630 psi at _stk/min psi at _stk/min ANN-VOL BBLS REAMING I spel -sun ( D~~~~- SERVICEs LOGGING SYSTEMS A ~I~NC. COWÞHf APPlED DRlWNG TECHNOlOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E I DEPTH 747818973 TVD) OPERA TION M/U BHA FOOTAGE 0 OPERATOR BP EXPLORATION I. CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 LCGGING DATA I AVG MAX AT GAS GAS DEPTH (units) (units) (feet) BACKGROUND 0 CONNECTION TRIP 610 7476 FLOWLINE TEMP 95 degrees F .l PORE PRESSURE FRACTURE PRESSURE _' ECD TIME TYPE WEIGHT IN FUNNEL VIS. PV /YP GELS pH Fll T/CAKE API HP-HT Pm Pf/Mf CHLORIDES ppm CALCIUM ppm Oil/WATER/SOLIDS DAilY/CUM. COST , DP - CSG ~ DP - HOLE l' DC - HOLE SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP lAG OFF BOTTOM 1?40 9250 NO. ~ DATE Aør 4 98 TIME 00 01 FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA (ið 7409.4 DS ?O.7 OFG "7 58.8 20% SHALE - 50% SilTSTONE - 20% SAND 1480 , , w.¡ 10.2 GPM 650 FEMARKS AND RECOMMENDATIONS JETS 3-15; 1-12 2500 PSI CASING 1247 psi. 9.0 1731 psi 12.5 1431 psi 10.3 FORMATION PFESSUFE DATA BOTTOM HOLE ppg 3554 pII 9.8 ppg ppg 5765 psi 15.8 ppg ppg 3135 psi 10.3 ppg BIT DATA DRilL RATE ftlhr CORRECTED "D· EXP. SHALE DENSITY glee EWR Res. 30 1.43 MUD MTA 4-4-98 KCl POLY 10.3, 61 25/25 10/28 8.4 4.0- 1/32 8,4 .0 .0/1.3 30000 120 1.0/89/8.4 5X133/8 LENGTH - FT. 2864 BIT NO. RR 4 TYPE MFDSSHCL IADC CODE W /MOTOR SIZE 12.25 JETS 15-15-15-12 DEPTH OUT 1476 ROT HRS. 12.0 +3.1 RM FOOTAGE 381 AVG ftlhr 31.8 GRADE 3-5-WT -A3-E HOLE DEV. 20 COST/FT 150 RPM 165 WOB 30/40 ANNlJI.AR DATA VOLUME BBlS/FT. VELOCITY FT/MIN .1241 OPEN HOLE psi ppg psi ppg psi ppg HYDfWJUC DATA 2. 101600 6X 12 4.22 80 ft ft ft 6 OH70 HFN POC/MOTOR 12.25 .7718 TFA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE atks/min 85 FLOW RATE aal/min 700 PRESSURE psi PD SURF I 08 psi ANN I BIT psi JET VELOCITY ftlsec JET IMPACT lb. BITHP HP RATIO I HP/lN2 REDUCED 1 RATE 2 STATIC pal at stk/min - psi at -,tk/min CRIT -VEL FT/MIN 285 ANN-VOL BBlS 5 X 12.25" .1215 285 8 X 12.25" 210 .0622 340 PIPE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2664 5.0 5.0 6.75 20.0- 1 3 3/8" 4.276 3.0 2.875 19.12 12.415 .0178 .0087 .0080 .355 .1498 .0075 .0181 .0362 .0334 .0240 638 210 110 2664 19.5 49 93 94 68 OD-inches 'I ID-Inchea CAP-bbls/ft DISP-bbls/ft lENGTH-ft L WEIGHT~b./It ftlmi = sec/std COMPLETE ELECTRIC lOGS IN BOTTOM SECTION OF HOLE BELOW 5300. RUN SIDEWAlL CORES. TEST BOP. MIU NEW BHA ON BIT NO.6. I I ~ ADT JOHN PATTON I. ( DEPTH 8:>85 '7877 TVD) OPERATION DRILLlNO FOOT AOE 705 OPERATOR BP EXPLORATION CONTRACTOR POOL ARcnc ALASKA I START DATE Mar 1098 -' I BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG GAS (units) 100 140 293 1?0 MAX GAS (units) 220 (' spe~y-sun lOGGING SYSTEMS· ~R~.n.~ cdirR« APPlED DFlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA AT DEPTH (f.el) 7980 J~57 7490 degrees F SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM NO. ?8 DATE Aør 7 98 TIME 00 01 FIELD/BLOCK AREA STATE tR) 8"4.7 0$ ?7.5 DFO A" ~8 . 50% SHALÈ - 30% SILTSTONE - 20% 8ANDSTONE A!>1 0 1380 10200 CASINO ~ PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 ECD 1437 p~ 1~3 MUD DATA FaWATION PRESSURE DATA BOTTOM HOLE ppg 3912 pal 9.8 ppg ppg 8350 psi 15.9 ppg ppg 4112 pli 10.3 ppg lIT DATA TIME ,I' TYPE WEIGHT IN .' FUNNEL VIS. PVfYP GELS pH Fll T/CAKE API HP-HT , Pm PfJMf ,,,," ' CHLORIDES ppm CALCIUM ppm OIl/WATER/SOLIDS DAllY/CUM. COST ,~ DP - C80 , DP - HOLE ..", :-~I' DC - HOLE -~- OD-inches ID-inches ,'IL CAP-bbls/ft DISP-bbls/ft LENGTH-ft WEIOHT-Ibs/ft 4-6-98 KCL POLY 10.2 60 15130 9/26 8.4 4.0- 2132 9.4 .12 .17<1.1 31000 100 0/89/9.3 5X133/8 lENGTH - FT. .2864 BIT NO. 7 TYPE OT -CPS09D IADC CODE W (MOTOR SIZE 12.25 JETS 16-16-16-14 DEPTH OUT ROT HRS. 21.3 FOOTAGE 775 AVG ftlhr 36.4 GRADE INC HOLE DEV. COST/FT 95 RPM 165 WOB 45 6 DH 70 HFN PDC/MOTOR 12.25 .7778 TFA 7490 2.1 16 7.6 O-O·BU-X-X·IN BALLED UP 165 10/50 DRill RATE ft/hr CORRECTED IDI EXP. SHALE DENSITY glee EWR Res. P.B.U. NORTH SLOPE ALASKA 35 1.51 OPEN HOLE psi ppg psi ppg psi ppg HYDRAULIC DATA 2. ID 1800 6X 12 4.22 85 PUMPS 1. ID 1600 SIZE Inche. 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stkl/min 86 FLOW RATE gal/min 725 PRESSURE psi PD SURF I D8 psi ANN I BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BITHP HP RATIO I HP/1N2 REDUCED 1 RATE 2 CRIT -VEL FTIMIN 245 255 390 DRill STRINO DC 8.0 2.875 .0080 .0545 210 149 CASING: COND DEPTH 11 0 20.01 19.12 .355 .0334 110 94 SURF 2664 13 3/8" 12.415 .1498 .0240 2664 88 ft ft ft 3200 75/2165 50191 0 318 1215 \ 385 28% . 3.3/1n2 psi at Itklmln - pll at Irk/mln - ANN·VOl BBlS MW 10.2 GPM 650 \ DRILL AHEAD IN MllUVEACH FORMATION. REPLACE APPROXIMATELY 1/3 OF MUD SYSTEM WITH FRESH MUD TO REDUCE CLAY SOLIDS. , TOP OF KINGAK AROUND 7800'. GOOD ROP FOR MOST OF THE DAY (45-50 FPH). DRILLING SLOWER IN HARDER SHALE AT MIDNIGHT (35 FPH). I ADT 5 X 12.25" 5391 8X12.25" 210 DP 5.0 4.276 .0178 .0075 7417 19.5 HWDP 5.0 3.0 .0087 .0181 638 49 JOHN P AnON ANNUlAR DATA VOLUME BBlS/FT. VELOCITY FT/MIN .1247 138 .1215 143 .0622 207 PIÆ DATA JETS ÆMÞJI<S AND RECOMMENDATIONS 3-15; 1-12 2700 PSI ftlmi = sec/std [ speÁ~~un ( DRILLING SERVICES lœGlNG SYSTE'MS AI.ItiItI:H~~ COWN« APPI.ED DRlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2'()1 RIG NAME RIG 8 LOC. SEC19-T12N-R11E ~ ~~~~~TION ~:tsaTW) FOOTAGE 10 -r OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA , START DATE Mar 1098 '> ~ BACKGROUND CONNECTION TRIP I FLOWLINE TEMP AVG GAS (unha) 90 105 .293 100 MAX GAS Cunha) 293 AT DEPTH (f..1) @TRIP 1540 7490 degrees F CASING PORE PRESSURE 1241 pal 9.0 FRACTURE PRESSURE 1731 pal 12.5 _r ECD 1437 p~ 1~3 ..;. TIME TYPE WEIGHT IN FUNNEL VIS. PV IYP ~ GELS pH - FIL T/CAKE API HP.f-IT Pm ~ Pf/Mf .~ CHLORIDES ppm CALCIUM ppm OIL/WATER/SOllDS DAILY ICUM. COST ~. DP - CSO .y OP - HOLE ,.,. , ;.:~ DC - HOLE .. ~ OD-Inchea ID-inche8 CAP-bbls/ft DISP-bbls/ft LENGTH-ft WEIGHT-Ibs/ft J' MUD DATA LDaGlNG DATA NO. 27 DATE Åpr 6 98 TIME 00 01 FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA ~ 7409.4 08 ?D.1 DFG A'" 58.6 30" SHALE - 60" SILTSTONE - 10% SANDSTONE .7550 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1?45 9300 FORIM11DN PRESSUfE DATA BOTTOM HOLE ppg 3593 pal 9.8 ppg PPO 5194 pal 15.8 ppg ppg 3777 psi 10.3 ppg lIT DATA 4-5-98 BIT NO. 7 6 KCl POLY TYPE GT -CPS09D DH70 HFN 10.2 IADC CODE W IMOTOR PDC/MOTOR 60 SIZE 12.25 12.25 21/18 JETS 16-16-16-14 .7778 TFA 11/25 DEPTH OUT 7490 8.3 ROT HRS. 3.6 2.1 3.9- 1/32 FOOTAGE 10 16 8.3 .15 AVG ftlhr 19.5 7.6 .2211.5 GRADE INC O·O-BU-X-X-IN 31000 HOLE DEV. BALLED UP 100 COST 1FT 315 1.0/89/8.6 RPM 165 165 WOB 35 10/50 5X133/8 LENGTH - FT. 2684 5 X 12.251 6686 ANNU.AR DATA VOLUME BBLSIFT. VELOCITY FT/MIN .1241 139 .1215 144 I MW 10.2 GPM 850 AElUJICS AND RECOMMENDATIONS JETS 3-15; 1-12 2700 PSI DRILL RATE ftJhr CORRECTED IDI EXP. SHALE DENSITY glee EWR Res. 35 1.41 OPEN HOLE psi ppg psi ppg pal ppg HYDfWJUC DATA 2. ID 1800 6X 12 4.22 86 PUMPS 1. ID 1600 81ZE Inches 6 X 12 CAPACITY oallstk 4.22 PUMP RATE stka/mln 88 FLOW RATE gal/mln 731 PRESSURE psi PD SURF I DS pal ANN I BIT psi JET VELOCITY ftJaec JET IMPACT Iba BIT HP HP RA 110 I HP/lN2 REDUCED 1 RATE 2 CRIT -VEL FT/MIN 230 230 ftlmi = It It It 3000 75/1960 40/925 318 1231 395 31% ·3.3/1n2 pal at atk/mln - psi at stk/mln - ANN-VOL BBLS sec/std POOH. CHANGE OUT BALLED UP PDC BIT. WORK ON ONE OF DRAW WORKS MOTORS - REMOVE AND REPAIR. RIH WITH NB NO.7. SLOW ROP ON BOTTOM WITH THIS BIT (6 FPH) . MORE BIT BALLING. PUMP PILL WITH SAPP. SOAP, + NUT PLUG. 30 FPH AFTER BIT CLEANED UP. DRill AHEAD. MAX GAS FROM TRIP - 293. 8X12.251 210 .0622 209 285 PIPE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2664 5.0 5.0 8.0 20.0- 13 3/81 4.276 3.0 2.875 19.12 12.415 .0178 .0087 .0080 .3S5 .1498 .0075 .0181 .0545 .0334 .0240 6712 638 210 110 2664 19.5 49 149 94 68 I j- AOT JOHN PATTON I 8~ j-sun LOGGING SYS~ ~~~k «»WIN( APPLED DRIWNG TECHNOlOGY MORNING REPORT WEll NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12M - R11E I DEPTH OPERATION FOOTAGE ,t~J m75 TVO) 110 I OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 LOGGING DATA t AVG MAX AT SURVEY DATA GAS GAS DEPTH LITHOLOGY (units) (unlta) (f.el) SAMPLE DEPTH BACKGROUND 100 218 8135 TRIP CHLORIDES I CONNECTION 15q 885? LAG DOWN DP TRIP NA 8885 LAG OFF BOTTOM - FLOWLINE TEMP 1?0 deare.s F NO. ~ DATE Ãpr 8 98 TIME 00 01 FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA (iiI 8"4.7 DS ?7.5 DFG AZ 58.8 40% SHALE - 40% SIL T$TONE - 20% SANDSTONE 8360 1395 10350 J CASING L _ PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 pal 12.5 ECD 1437 pai 10.3 MUDI:MTA 4-8-98 KCl POLY 10.2 67 17/26 _'7/32 8.4 5.1- 2/32. 11.1 o 0/1.3 28000 180 2188/8.5 FORMATION PRESSURE DATA BOTTOM HOLE ppa 3982 pal 9.8 ppa ppa 6428 pal 15.9 ppa ppg 4184 pal 10.3 ppg lIT DATA TIME TYPE WEIGHT IN FUNNEL VIS. PV IYP GELS I pH . FllT/CAKE API HP.ffi" I. DP - CSG 5X133/8 LENGTH - FT. 2684 BIT NO. 7 TYPE GT -CPS09D IADC CODE W IMOTOR SIZE 12.25 JETS 18-16-18-14 DEPTH OUT 8375 ROT HRS. 24.9 FOOTAGE 885 AVG ft/hr 35.5 GRADE 8-4-BT-A3-F-1 HOLE DEV. 27.5 COST 1FT 92 RPM 185 WOB 45 ANNULAR DATA VOLUME BBLSIFT. VELOCITY FTIMIN .1247 138 8 GT090 W IMOTOR 12.25 18-18-18·14 I Pm PtlMt CHLORIDES ppm CALCIUM ppm OIL/WATER/SOUDS I. DAILY/CUM. C08T 1 DP . HOLE 5501 .1215 143 5 X 12.25' DRill RATE ft/hr 28 CORRECTED "D" EXP. 1.55 SHALE DENSITY alee EWR Rei. OPEN HOLE pal ppa pal p Pel pal PPel HYDIWJUC DATA 2. ID 1800 8X 12 4.22 85 PUMPS 1. ID 1800 SIZE Inehe. 8 X 12 CAPACITY aal/atk 4.22 PUMP RATE atka/mln 88 FLOW RATE aal/mln 725 PRESSURE pal PD SURF I DS pai ANN I BIT psi JET VELOCITY ft/aee JET IMPACT lb. BIT HP HP RATIO I HPßN2 REDUCED 1 RATE 2 CRIT-VEl FT/MIN 280 280 ~ " f':¡ ---.- DC - HOLE 8 X 12.25" 210 .0622 207 390 1 fIFE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2684 OD-Inche. 5.0 5.0 8.0 20.0- 13 3/8" l ID-Inche. 4.278 3.0 2.875 19.12 12.415 CAP-bbls/ft .0178 .0087 .0080 .355 .1498 DISP·bbla/ft .0075 .0181 .0545 .0334 .0240 LENGTH·ft 7527 838 210 110 2664 WEIGHT-Iba/ft 19.5 49 149 94 68 [MW GPM REUNI(S AND RECOMMENDATIONS 3-15; 1·12 2700 PSI 10.2 650 JETS ft/mi It It It 3250 75/2215 50/91 0 316 1215 385 28% - 3. 3 /in2 pal at -,tk/mln pal at -,tk/mln ANN·VOl BBlS = sec/std DRill AHEAD WITH BIT NO.7 TO 8375'. PROBLEM DEVELOPED WITH RIG SCR PANEL CIRCULATE AND WORK ON SCR #3. POOH TO SHOE. INSTAllED REPAIRED TRACTION MOTOR. POOH. BEARING FAILURE NOTED ON BIT NO.7. MIU NB NO.8. RIH. ADT JOHN PATTON J I, -' DEPTH 7T4.90 (6986 TW) OPERATION "RIP FOOTAGE 18 1 OPERATOR BP EXPLORATION .. CONTRACTOR POOL ARCTIC ALASKA START DATE M.,10 98 ) I J BACKGROUND CONNECTION ,I TRIP FLOWLINE TEMP AVG GAS (units) 55 MAX AT GAS DEPTH (units) (feel) ( ( sperry-sun DRILLING 8ERvlCE8 Lt:Jt3(;ING SYSTEMS A Dti:a::H ~I~ He. COJIt"IN{ APPUED DRlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19-T12N-R11E I.DGGING DATA NO. 26 DATE ADr 5 98 TIME 00 01 FIELD/BLOCK AREA STATE tið 7409.4 DS 90.7 DfG /47 58.6 20% SHALE - 50% 81L T8TONE - 20% SAND 7490 7476 degree. F 8URVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1,140 9250 480 90 00, I CASING PORE PRE8SURE 1247 pal 9.0 FRACTURE PRESSURE 1731 psi 12.5 ECD 1437 pal 10.3 IlUJDATA FCRIA11CN PRESSUÆ DATA BOTTOM HOLE ppg 3580 psi 9.8 ppg ppg 5740 psi 15.8 ppg ppg 3742 pll 10.3 ppg BIT DATA ...:;.. TIME TYPE o' WEIGHT IN FUNNEL VIS. PV /YP GELS ,I pH FILT/CAKE API HP-HT Pm .d PfIMf CHLORIDES ppm 1 CALCIUM ppm OIUW A TER/SOllDS .JI DAILY/CUM. COST ~ DP - CSG ~",',"" t~ DP - HOLE DC - HOLE ~ OD-inches , liD-Inches CAP-bbla/ft DISP-bbls/ft LENGTH-ft WEIGHT-Iba/ft ....1 WI 10.2 4-5-98 KCL POLY 10.2 60 , 21 {18 11/25 8.3 3.9- 1/52 8.3 .15 .22/1.5 31000 100 1.0/89/8.6 5X13318 LENGTH· FT. 2684 BIT NO. RR 4 TYPE MFDSSHCL IADC CODE W ¡MOTOR SIZE 12.25 JET8 1 5-15-15·12 DEPTH OUT 7476 ROT HRS. 12.0 +3.1 RM FOOTAGE 381 AVG ft/hr 31.8 GRADE 3·5·WT·A3·E HOLE DEV. 20 COSTIFT 150 RPM 165 WOB 30/40 6 DH70 HFN PDCIMOTOR 12.25 .7778 TFA 7490 2.1 16 7.6 165 1 0150 DRILL RATE ftJhr CORRECTED "D" EXP. 8HALE DENSITY glee EWR Rea. P.B.U. NORTH 8LOPE ALASKA 6 '..15 OPEN HOLE psi ppg pli ppg pII ppg HYDRAUlIC DATA 2. ID 1 fJOO 6X 12 4.22 83 PUMP8 1. ID 1 BOO 81ZE Inches 6 X 12 CAPACITY gal/ltIc 4.22 PUMP RATE atks/min 83 FLOW RATE g_lImln 700 PRESSURE psi PD SURF I DS psi ANN / BIT pal JET VELOCITY ft/I.C JET IMPACT lb. BIT HP HP RATIO / HPIIN2 REDUCED 1 RATE 2 CRIT -VEL FT/MIN 230 230 285 DRILL STRING DC 8.0 2.875 .0080 .0545 210 149 CASING: COND DEPTH 110 20.0" 19.12 .355 .0334 110 94 SURF 2664 13 3/8" 12.415 .1498 .0240 2664 68 JETS ÆMI\RKS AND RECOMMENDATIONS 3-15; 1..12 2500 PSI ft ft It 2700 75/1830 35/780 289 1067 310 ~8% - 2.6 Iin2 psi at stklmln - pal at stklmln - ANN·VOL BBLS = sec/std 5 X 12.25" 4616 AtN.I.AR DATA VOLUME BBLSIFT. VELOCITY FT/MIN .1247 133 .1215 131 ftlmi RIH. TRY TO DRILL WITH BIT NO.6. MAX GAS - 460. BIT APPEARED TO BAU UP OR POSSIBLE MOTOR FAILURE - NO BITE ON BOTTOM. POOH TO 4750. COULD NOT GET TRIP TANK TO FUNCTION PROPERLY IN ORDER TO MONITOR HOLE FILL. AlH. CBU. MAX GAS.. 202. REPAIR· CLEAN VALVE IN TRIP TANK SYSTEM. POOH. . {' APT 8 X 12.25" 210 DP 5.0 4.276 .0118 .0075 6642 19.5 HWDP 5.0 3.0 .0087 .0181 638 49 GPM 650 JOHN PATTO~ .0622 199 PIÆ DATA s·- .. ~ It spe~J'-sun D~~~~18~RVlCE8 lOGGING SYSTEMS A tdJbl~NC. r:bIrN« APPI.ED DRIWNG TEaiNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-Ð1 RIG NAME RIG 8 LOC. SEC 19 - T12N - RUE ;, DEPTH 8705 (8075 TVD) OPERATION DRILLING .. FOOTAGE 330 f OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 ,., AVO MAX AT .. GAS GAS DEPTH ~ (units) (units) (feeO BACKGROUND 200 315 8895 ~ CONNECTION ?40 8865 I I TRIP 507 8375 .. FLOWLINE TEMP 1?O degre., F "'" ,1 :31 CASING 'P PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 ..T ECD 1437 pal 10.3 :> TIME ¡' TYPE WEIGHT IN FUNNEL VIS. PVNP -,I' GELS ~ pH ',' ~ FIL T ICAKE API I HP-HT ",' ,Pm : i Pf/Mf ,>. I' CHLORIDES ppm CALCIUM ppm , OIL/WATERISOUDS : I DAIL V ICUM. COST ~ ' 1.' I- DP· CeG . DP . HOLE 1 ~ I DC - HOLE 1 ·,loD-inche. ID·lnehes . I CAP·bbls/ft DISP·bbls/ft d LENGTH·ft P WEIGHT·lbs/ft [ MUD DATA 4-9-98 KCL POLY 10.2 59 18/28 19/48 8.7 G.1· 2132 13.2 .31 .211.8 30000 185 '/88/8.7 5X133/8 LENGTH· FT. 2884 LCGGING DATA NO. 30 DATE Apr 9 98 TIME 00 01 FIELD/BLOCK AREA STATE (8) 8411.9 De ?5.5 DFG A'1 59.8 70% SHALE - 20% SILTSTONE - 10% SANDSTONE 8380 SURVEY DATA LITHOLOGY SAMPLE OEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1465 1 0900 DRILL RATE ftlhr CORRECTED aD' EXP. SHALE DENSITY g/ee EWR R.I. P.B.U. NORTH SLOPE ALASKA 45 1.45 OPEN HOLE psi ppg pli ppg pli ppg ttYDRAUUC DATA 2. ID 1600 GX 12 4.22 86 PUMPS ,. ID 1600 SIZE Inche, 8 X 12 CAPACITY gal/stk 4.22 PUMP RATE atka/mln 88 FLOW RATE gal/mln 725 PRESSURE pai PO SURF I OS pli ANN I BIT psi JET YELOCITY ft/.ee JET IMPACT Ibs BIT HP HP RATIO I HPIIN2 REDUCED 1 RATE 2 CRIf ·YEL FT/MIN 280 280 8 X 12.2& 210 .0822 207 390 ..-e DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2684 5.0 5.0 8.0 20. ()I 13 3{8' 4.276 3.0 2.875 19.12 12.415 .0178 .0087 .0080 .355 .1498 .0075 .0181 .0545 .0334 .0240 7880 638 210 110 2664 19.5 49 149 94 68 5 X 12.25' 5831 FORIM11DN PRESSURE DATA BOTTOM HOLE ppg 4200 pai 10.0 ppg ppg 6718 psi 15.9 ppg ppg 4387 pll 10.4 ppg BIT DATA BIT NO. 7 TYPE GT ·CPS09D IADC CODE W IMOTOR SIZE 12.25 JETS 16-16·16-14 DEPTH OUT 8375 ROT HRS. 24.9 FOOTAGE 885 AVG ft/hr 35.5 GRADE 6-4·BT·A3-F·1 HOLE DEV. 27.5 COST/FT 92 RPM 165 woe 45 8 GT090 W IMOTOR 12.25 16-18-18-14 12.0 330 27.5 25.5 181 170 40/45 It It It 3300 75/2285 50/91 5 316 1215 390 28% - 3.3 lin2 pli at -:,tklmln psi at -:,tklmln ANN·VOL BBlS FEMNI<s AND RECOMMENDATIONS '.WfN 10.2 GPM 650 JETS 3-15; 1-12 3200 PSI ftIml = _ seclstd fRIH. DRILL AHEAD WITH BIT NO.8. MAX GAS FROM TRIP - 507. SLOW ROP IN HARDER SHALE. ROP INCREASE NOTED AT 8600 CHANGING I 'FROM 25 TO 45 FPH. RAISE PORE PRESSURE EST1MATE TO 10.0 PPG WITH THIS CHANGE RELATIVE TO TRENDS ON Dc EXPONENT AND I CONDENSED RESISTIVITY PLOTS. I IIIADT J9HN PA TT9N ANNULAR DATA VOLUME BBLSIFT. VELOCITY FT/MIN .1247 138 .1215 143 I, I DEPTH '880 (AW'M» ,. OPERATION· TEST sõP FOOTAGE 155 ( ( 8pe~ -sun \ D~~{8ERYlCE' lOGGNG SYSTEMS A tuAiltÐ ~ COJIrÞN'f APPLIÐ DflWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-()1 RIG NAME RIG 8 LOCo SEe 19· T12N. R11E 1,' OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 I BACKGROUND CONNECTION TRIP · FLOWLINE TEMP FIELD/BLOCK AREA STATE LCaGlNG DATA (ftl 8893.7 DS 17.9 DFG ^l ~.8 . 80% SHALE . 20% SILTstoNe 8840 AVG MAX AT SURVEY DATA GAS GAS DEPTH LITHOLOGY (units) (units) (feet) SAMPLE DEPTH 130 204 8730 TRIP CHLORIDES LAG DOWN DP 507 8375 LAG OFF BOTTOM 1?O degre.s F 1485 11 050 1 CASING , PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 pel 12.5 ,,,," EeD 1437 pel 10.3 MlI) D.\TA FORMATION PfESSURE DATA BOTTOM HOLE ppg 4280 pal 10.0 ppg ppg 6848 psi 15.9 ppg ppg 4408 pal 10.3 ppg BIT DATA TIME ,- TYPE WEIGHT IN FUNNEL VIS. PV IVP - I GELS pH .. FILT/CAKE API HP-HT "i'i Pm PflMf ... CHLORIDES ppm CALCIUM ppm Oll/WATERISOUDS , DAilY/CUM. COST 4·10-98 KCl POLY 10.2 63 19/32 21/43 8.5 5.6- 2132 11.6 .05 .05/1.8 29000 80 '/8819.4 DP . CSG 5X133/8 I DP . HOLE 5 X 12.25" ~ DC . HOLE 8 X 12.25' OD·lnche. ID-inches CAP-bbls/ft DISP-bbls/ft LENGTH·ft WEIGHT -Iba/ft DP 5.0 4.278 .0178. .0075 8012 19.5 MW 10.2 GPM 650 BIT NO. 9 TYPE MFDS8HCR IADC CODE W IMOTOR SIZE 12.25 JETS 18·18-16·16 DEPTH OUT ROT HRS. FOOTAGE AYG ft/hr GRADE HOLE DEV. COST/FT RPM WOB 8 GT09D W IMOTOR 12.25 18-16-16-14 8860 18.6 485 26.1 8-8-BC-1 +2.f 18 144 170 45 NO. 31 DATE Apr 10 98 TIME 00 01 P.B.U. NORTH SLOPE ALASKA DRILL RATE ftJhr 10 (LAST FOOT) CORRECTED "D" EXP. 1.68 SHALE DENSITY glee EWR Rei. OPEN HOLE pll ppg pli ppg plI ppg HYDIWJUC DATA 2. ID 1600 6X 12 4.22 86 It It ft PUMPS 1. to 1600 SIZE Inch.. 6 X 12 CAPACITY gal/stlc 4.22 PUMP RATE stka/min 86 FLOW RATE gal/min 725 PRESSURE psi PD SURF I DS pai ANN 1 BIT psi JET VELOCITY ftla.c JET IMPACT lb. BIT HP HP RATIO I HPIIN2 REDUCED 1 RATE 2 HWDP 5.0 3.0 .0087 .0181 638 49 DRILL STRING DC 8.0 2.875 .0080 .0545 210 149 CASING: COND DEPTH 110 20.0" 19.12 .355 .0334 110 94 CRIT-YEl FTIMIN 300 300 415 SURF 2664 1 3 3/8" 12.41 5 .1498 .0240 2684 68 ftlmi = 3300 75/2265 501915 316 1215 390 28% . 3.3 11n2 pll at Itklmln - pel at Itklmin - ANN-VOL BBLS see/stet DRILL AHEAD WITH BIT NO.8 IN KINGAK FORMATION. HIGH TORQUE NOTED AFTER MAKING CONNECTION AT 8852. DRILL TO 8860. CIRCULATE AND PUMP SLUG. POOH. HEAYY DAMAGED NOTED TO BIT 8 UPON INSPECTION AT SURFACE. TEST BOP'S. ,~ ADT LENGTH - FT. 2684 ANNUlAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .1247 138 5986 .1215 143 210 .0622 207 PIlE DATA JETS FEMAAKBAND RECOMMENDATIONS 4-151s 3200 PSI JOHN PATTON I r ~ DEPTH 8~ (8358 TVO) OPERATION DRilLING FOOTAGE 135 sper{7 -sun (' DRilLING SERVICES lCXJGING SYSTEAIS A Ltt:ta:tt tuJt;1~ I\IC. ~IH{ NJPlED DRlWNG TECHNOLOGY MORNING REPORT WEll NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E - OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA I START DATE Mar 1098 BACKGROUND CONNECTION TRIP FLOWLINE TEMP -J' AVG GAS (units) 125 150 100 115 LCaGlNG DATA MAX GAS (units) 160 AT DEPTH (f.el) 8885 8918 8880 degre., F SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1505 11150 CASING .. PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 pal 12.5 ECD 1440 psi 10.4 MUD DATA FORMATION PRESSURE DATA BOTTOM HOLE ppg 4348 psi 10.0 ppg ppg 6954 pal 18.0 ppg ppg 4520 pai 10.4 ppg BIT DATA TIME " . TYPE WEIGHT IN FUNNEL VIS. PV /YP GELS pH FILT/CAKE API HP-HT " Pm I PfIMf CHLORIDES ppm CALCIUM ppm r OIL/WATERISOllDS DAILY/CUM. COST ~ " ~ DP - CIG ,~ DP ~ HOLE 9] ·Lf L!" DC - HOLE J ¡ OD-Inches ID -inches CAP-bbla/ft DISP-bbls/ft LENGTH-ft WEIGHT -Iba/ft 4-10-98 KCL POLY 10.3 48 18/20 1 5129 9.1 4.2- 2/32 9.3 .22 .2011.3 30000 120 2/8819.1 5X133/8 5 X 12.25w 8 X 12.251 DP .5.0 4.278 .0178 .0015 8148 19.5 MW 10.3 GPM 650 BIT NO. 9 TYPE MFDSSHCR IADC CODE W IMOTOR SIZE 12.25 JETS 18-16-18-16 DEPTH OUT ROT HRS. 6.9 FOOTAGE 135 AVG ftlhr 19.6 GRADE HOLE DEV. 14.5 COST 1FT . 295 RPM 170 WOB 48 8 GT09D W IMOTOR 12.25 18-18-18-14 8880 18.8 485 26.1 8-8-BC-1 +2-F 18 144 170 45 NO. !t~ DATE Aþr 11 98 TIME 00 01 FIELD/BLOCK AREA STATE DRILL RATE ftlhr CORRECTED 101 EXP. SHALE DENSITY ø/ee EWR Res. P.B.U. NORTH SLOPE ALASKA 30 1.60 OPEN HOLE psi ppg psi ppg psi ppg HYDfWJUC DATA 2. ID 1800 8X 12 4.22 85 PUMPS 1. 10 1600 SIZE inches 8 X 12 CAPACITY aaVatlc 4.22 PUMP RATE stks/min 85 FLOW RATE g_l/mln 721 PRESSURE pai PD SURF IDS psi ANN 1 BIT psi JET VELOCITY ftlaec JET IMPACT Ibs BIT HP HP RATIO 1 HP/lN2 REDUCED 1 RATE 2 CAIT -VEL FT/MIN 260 260 300 HWDP 5.0 3.0 .0087 .0181 638 49 DRILL STRING DC 8.0 2.875 .0080 .0545 209 149 CASING: COND DEPTH 110 20.01 19.12 .355 .0334 110 94 SURF 2684 1 S 3/8w 12.415 .1498 .0240 2664 88 It It It 32SO 15/2325 501800 295 1130 335 24% . 2.8/in2 psi at stklmln - psi at stklmln - ANN·VOL BBLS sec/std RtH WITH BIT NO.9. DRILL AND WORK JUNK LEFT ON BOTTOM OF THE HOLE FROM LAST BIT RUN. HIGH TORQUE AND SLOW ROP RECORED AT START OF RUN. MAX GAS FROM TRIP - 700. MORE SHALE SLOUGH AND LONGER TRIP GAS PEAK NOTED FROM BOTTOM. RAISE MUD WEIGHT TO 10.3. DRILL AHEAD. ADT @ f91 ?8 DS 14.5 D~G Þ\l 54.7 10% SHALE - 30% 81LTSTÓNE 8940 LENGTH - FT. 2664 AtNJLAR DATA VOLUME BBLSIFT. VELOCITY FT/MIN .1247 137 8122 .1215 141 209 205 .0822 ÆJE DATA JETS fEMNI(S AND RECOMMENDA11ONS 4-15'. 3200 PSI '¿OHN PATTO~ ft/mi = I. . ( 8~~.t~ LOGGING SYSTEMS ~~I~'k. CQlrNfi APPlED DFlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E r. DEPTH 9?80 (8043 TW) OPERATION CIRCULATING FOOT AGE ~5 I OPERATOR BP EXPLORATION . CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 D8 r. I BACKGROUND (CONNECTION .. ~~~WLlNE TEMP 1. 1 ( I. LCaGING DATA AVG AT MAX NO. 33 DATE Apr 12 98 TIME 00 01 FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA tAl ~4.6 DS e.n DFG A759.1 "ACK. aw....¡; - ~ ..... TATQNIõ 8?80 SURVEY DATA ....TWO...OQV SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM ....... \aA~ (units) 300 350 1430 1" GÂÞ (unfta) 363 Û~t:ìt1 (feel) 9165 9197 9260 degree. F 1555 11700 CASING PORE PRESSURE 1247 pal 9.0 FRACTURE PRESSURE 1731 pal 12.5 ECD 1482 pal 10.7 FORMA11ON PRESSUfE DATA BOTTOM HOLE ppg 4585 pal 10.2 ppg ppg 7190 pal 18.0 ppg ppg 4810 pal 10.7 ppg lIT DATA TIME TYPE WEIGHT IN FUNNEL VIS. PV /yP GELS pH FIL T/CAKE API HP-HT Pm P'IM' ., 1 CHLORIDES ppm CALCIUM ppm OIL/W A TER/SOllDS DAIL V /CUM. COST MUD IMTA 4-12-98 KCL POL V 10.6 50 20/22 17/39 9.1 4.8- 2f32 10.1 .30 .20/1.9 29000 120 1/88/9.4 BIT NO. 9 TYPE MFD8SHCR IADC CODE _ W /MOTOR SIZE 12.25 JETS 16-16-16-18 DEPTH OUT 9280 ROT HRS. 16.0 FOOTAGE 420 A VG ftlhr 26.3 GRADE HOLE DEV. 8.2 COST /FT 155 RPM 170 WOB 48 8 GT090 W /MOTOR 12.25 16-16-18-14 8860 18.8 485 26.1 8-8-BC-1 +2·F 18 144 110 45 DRILL RATE ftlhr CORRECTED "D" EXP. SHALE DENSITY glee EWR Res. 30 1.80 OPEN HOLE psi ppg psi ppg psi ppg HYDRAULIC DATA 2. to 1800 6X 12 4.22 85 It It It PUMPS 1. 10 1600 SIZE Inches 8 X 12 CAPACITY gal/ltk 4.22 PUMP RATE atka/min 85 FLOW RATE gal/mln 123 PRESSURE psi PO SURF / OS pal ANN I BIT pal JET VELOCITY ft/sec JET IMPACT lb. BITHP HP RATIO I HP/lN2 REDUCED 1 RATE 2 3350 15/2395 55/825 295 1130 335 . 24% - 2.8/in2 psi at Itklmln - psi at Itklmln - ANNULAR DATA LENGTH - FT. VOLUME BBLS/FT. VELOCITY FT/MIN CRIT -VEL FT/MIN ANN-VOL BBLS DP - CSG 5X133/8 2664 .1241 131 265 DP . HOLE 5 X 12.25" 8401 .1215 142 265 .., DC - HOLE 8 X 12.25' 209 .0822 208 310 PFE DATA DRill STRING CASING: COND SURF DP HWDP DC DEPTH 110 2864 , I OD-Inche. 5.0 5.0 8.0 20.0" 13 3/8' \ ID-Inche. 4.276 3.0 2.875 19.12 12.415 , CAP-bbls/ft .0178 .0087 .0080 .355 .1498 DISP-bbls/ft .0015 .0181 .0545 .0334 .0240 (LENGTH.tt 8433 838 209 110 2864 : WEIGHT -Iba/ft 19.5 49 149 94 88 . I FEMMKS AND RECOMMENDATIONS I MW 10.5 GPM 650 JETS 4-15'8 3300 PSI ftImi = _ sec/std [DRILL AHEAD TO CASING POINT AT 9280. INCREASE IN BACKGROUND GAS FROM 150 AVERAGE TO 300 AVERAGE FOR LAST 150' OF HOLE rFROM SLIGHT INCREASE IN SHALE SLOUGH. PORE PRESSURE ESTIMATE RAISED TO 10.2 RELATIVE TO GAS, RESISTIVITY, AND 0 EXPONENT , . TRENDS. MUD WEIGHT RAISED TO 10.8 PPG BEFORE SHORT TRIP. taU AND PUMP SWEEP. PULL 20 STANDS. MODERATE DRAG ON WAY . OUT. RIH. REAM/WORK TIGHT SPOTS FROM 8828.8850.8718.8843.8874,8889 (SECOND PRESSURED ZONE IN KINGAK). MAX GAS FROM REAMING , I- 1430 WITH INCREASE IN SHALE SLOUGH. TIH TO BOTTOM. CIRCULATE, PUMP SWEEP. MAX GAS FROM BOTTOM - 410. .- IADT JOHN PATTON { ( ~pent-8Un l~NG S~'ft:2~ ~~j\~::::: T~IC=~ APPLED DFlWNG TECHNOLOOY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. tEC 1sa - T12N - R11E I I [DEPTH 9. (8843 TYe) 'I OPERATION RUNNING 9 5/8' FOOTAGE 0 [ I OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA J I.TART DATE Mar 1098 { IDGGING DATA AYO MAX AT GAS GAS DEPTH (unlta) (unlta) ('.81) BACKGROUND 30 LAST CIRC CONNECTION TRIP 310 9280 FLOWLINE TEMP 1?O d.gr.ea F SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM l 1 1 TIME l TYPE WEIGHT IN .' FUNNEL VIS. PV /yP _ GELS I pH I FIL TICAKE API HP-HT I ~;Mf :J CHLORIDES ppm CALCIUM ppm OIL/WATER/SOUDS DAilY/CUM. COST 1555 11 700 CASING PORE PRESSURE 1247 pal 9.0 FRACTURE PRESSURE 1731 pal 12.5 ECD 1482 pal 10.7 FORMA11CN PRESSURE DATA BOTTOM HOLE ppg 4585 pal 10.2 ppg ppg 7190 pal 16.0 ppg ppg 4810 pal 10.1 ppg Elf DATA IAJDDATA 4-13-98 KCL POLY 10.7 42 13/16 10/0 8.5 4.9- '/32 10.0 o .1 0/1 .7 30000 120 2187.5/8.9 BIT NO. 9 TYPE MFDSSHCR IADC CODE W /MOTOR SIZE 12..25 JETS 16-16-16-16 DEPTH OUT 9280 ROT HRS. 16.0 FOOTAGE 420 AVO ft/hr 26.3 GRADE 6-6-BT-M-E HOLE DEV. 8.2 COST/FT 155 RPM 170 WOB 48 8 GT090 W/MOTOR 12.25 16-16-16-14 8860 18.6 485 26.1 8-a-BC-1 +2-F 18 144 170 45 NO. 34 DATE ADr 13 98 TIME 00 01 FIELD/BLOCK AREA 8TATE DRILL RATE ftlhr CORRECTED "0" EXP. SHALE DENSITY wee EWR R.a. P.B.U. NORTH SLOPE ALASKA 30 1.60 OPEN HOLE pal ppg psi ppg pal ppg HYDFWJUC DATA 2. ID 1600 ex 12 4.22 PUMPS ,. ID 1600 "ZE Inehe. 6 X 12 CAPACITY gal/atk 4.22 PUMP RATE atka/mln 98 FLOW RATE gal/mln 413 PRESSURE pal PD SURF / DS pal ANN / BIT psi JET VELOCITY ft/.ee JET IMPACT Ib, BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CSG - CSG lENGTH - FT. 2664 MNJlAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0598 184 CRIT -VEL FT/MIN 380 tRI 9?14.6 08 8." DFG /4759.1 . 50% SHALE - 50% SILTSTONE 9?80 95/8-12.4 j C SG-HOLE 95/8-12.2 -.0558 [I :":".J It ft It 1500 70/1380 pll at stklmln - pll at atklmln - ANN-VOL BBlS PIPE DATA DRILL STRING CASING: COND SURF INTER DP HWDP DC DEPTH 110 2664 OD-Inches 5.0 5.0 20.0' 1 3 3/8' 9 5/8" ID-Inches 4.276 3.0 19.12 12.415 8.681 CAP-bbls/It .0178 .0087 .355 .1498 .0132 DISP·bbls/1t .0015 .0181 .0334 .0240 .0168 LENGTH-It 110 2664 WE IGHT ·Iba/It 19.5 49 94 68 47 FEMARKB AND RECOMMENDATIONS MW 10.5 GPM JETS ftlmi = see/stet __J I I 1 POOH 10 STANDS. HOLE TIGHT ON FIRST STAND. RIH. CIRCULATE. PUMP SWEEP. MAX GAS FROM TRIP - 310. POOH. HOLE PULlED I GOOD ON WAY OUT· NO TIGHT SPOTS. LJD 8" BHA. CHANGE OUT TOP RAMS. R/U TO RUN CASING. RUNNING 47# l-80 9 5/8" CASING. RIH TO 13 3/8 SHOE. CBU. MAX GAS - 90. RIH. . I ,J ADT JOHN P~TTON I I I I DEPTH OPERATION FOOTAGE EJ~:r()) o OPERATOR BP EXPLORATION r CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 ~ I AYO MAX AT GAS GAS DEPTH (unlh) (unltl) (feel) BACKGROUND 60 CONNECTION TRIP 700 9280 FLOWLINE TEMP 80 degr.e. F CASING PORE PRESSURE 1247 psi 9.0 FRACTURE PRESSURE 1731 psi 12.5 ECD 1538 psi 11.1 IlUDDATA ..:... TIME TYPE WEIGHT IN FUNNEL VIS. PV /YP GELS pH FIL T/CAKE API HP+IT 4-13-98 KCL POLY 10.7 42 13/10 10/0 8.5 4.9- 1/32 10.0 o .10/1.7 30000 120 2/87.5/8.9 Pm Pf/Mf =- CHLORIDES ppm CALCIUM ppm r 0lLIWATERISOllD8 DAIL Y ICUM. COST 'j C80 - CSo LENOTH - FT. 2ð84 9 5/8-12.4 .. CSG-HOLE 9 5/8-12.2 'f '~~ L.CaGING DATA lRi 9?14.Q. os 8." D~t ,.7 ,.7 50% SHALE - 50% SIL"YstÓN 9~ sperf ..un (' DR~~f SERVICES LOGGING SYSTEMS A ~I~NC. COJIrlNf APPLIÐ DFlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2'()1 RIO NAME RIG 8 LOC. SEC 19 - 112N - R11E SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 6750 5850 NO. 35 DATE Apr 1498 TIME 00 01 FIELD/BLOCK AREA STATE r.p.u. NORTH SLOPE ALASKA FaWA110N pp::pot.JfE DATA BOTTOM HOLE ppg 4585 pII 10.2 ppg ppg 7190 pal 18.0 ppg ppg 5034 psi 11.1 ppg lIT DATA BIT NO. 9 TYPE MFDSSHCR IADC CODE W IMOTOR SIZE 12.25 JETS 16-18-16-16 DEPTH OUT 9280 ROT HRS. 16.0 FOOTAGE 420 AVG ftlhr 26.3 GRADE 6-6-BT·M·E HOLE DEV. 8.2 COST 1FT 155 RPM 170 WOB 48 AN«JLAR DATA VOLUME BBLSIFT. YELOCITY FT/MIN .0598 187 CASING 95/8 .0558 179 DRILL RATE ftlhr CORRECTED "0" EXP. SHALE DENSITY glee EWR Rea. 30 1.60 OPEN HOLE psi ppg psi ppg psi ppg HYDRAULIC DATA 2. 101600 8X 12 4.22 It It It PUMPS 1. ID 1600 SIZE Inch.s 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE atka/mtn 101 FLOW RATE gal/mln 425 PRESSURE pal PO SURF I DS psi ANN I BIT psi JET VELOCITY ftJaec JET IMPACT lb. BITHP HP RATIO I HP/IN2 REDUCED 1 RATE 2 610 7~250 285/- CIRCULA TING BEHIND CASING pal at atk/mln - psi at stk/mln - CRn -YEl fTIMIN 360 ANN-VOL BBLS 385 PFE DATA DRILL STRING CASINO: COND SURF INTER -~ DP HWDP DC DEPTH 110 2664 OD·inches 5.0 5.0 20.0" 1 3 3/8" 9 Sl8' ID-Inches 4.276 3.0 19.12 12.415 8.681 CAP-bbls/ft .0178 .0087 .355 .1498 .0732 DISP-bbls/ft .0075 .0181 .0334 .0240 .0168 LENGTH-ft 110 2664 WE I GHT-Iba/ft 19.5 49 94 68 47 -. Fl'JþJICS AND RECOMMENDATIONS MW 10.5 GPM JETS ftlmi = see/std .' - RUN 9 5/8 CASING TO BOTTOM WITHOUT PROBLEMS. CIRCULATE AND CONDITION HOLE. MAX GAS FROM BEHIND CASING - 700 UNITS. WASHOUT HIGH PRESSURE MUD LINE. BYPASS LINE. RIU fOR CEMENT JOG. CEMENT FIRST STAGE A8 PER WEU PROGRAM. DISPLACE AND BUMP PLUG. GOOD RETURNS ON THIS CEMENT JOB. PRESSURE UP ES CEMENTER TO 2700 PSI TO RELEASE. CIRCULATE THROUGH ES CEMENTER. MIX AND PUMP 8ECOND STAOE - 20 BBL H2O. 50 BBL SPACER 530 BBL+ CEMENT. I , ADT JOHN PATTON I. I ( ( sper\t-SUn DRILLING SERVICES lCJGG/NG SYSTJ:MS A J:ÆSSER NJUSlŒS NC. CONPÞHf APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19· T12N - R11E DEPTH 9280 (8643 TVD) OPERA nON DRILL CEMENT FOOTAGE 0 I'. OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 lOGGING DATA I. AVG MAX AT GAS GAS DEPTH (units) (units) (feet) [ BACKGROUND 8 CONNECTION TRIP 15 9186 FLOWLINE TEMP 88 degrees F SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM FIELD/BLOCK AREA STATE @ 9214.6 DS 8.22DEG AZ 59.7 CEMENT 9186 1555 4350 1 CASING .;.,' PORE PRESSURE 4582 psi 9.0 FRACTURE PRESSURE NA psi ECD psi FORMA11ON PRESSURE DATA BOTTOM HOLE ppg 4585 psi 10.2 ppg ppg 7190 psi 16.0 ppg ppg IN psi CSG ppg BIT DATA TIME , TYPE WEIGHT IN . FUNNEL VIS. PV/YP .. GELS pH ~ Fll T/CAKE API HP-HT ,r Pm Pf/Mf ~ CHLORIDES ppm CALCIUM ppm Oil/WATER/SOLIDS DAIL Y ICUM. COST MUD DATA 4-15-98 KCl POLY 10.7 48 14/20 6115 8.5 5.0- 1{32 10.3 o .10/1.5 30000 100 2/88/8.4 BIT NO. 9 TYPE MFDSSHCR IADC CODE W/MOTOR SIZE 12.25 JETS 16-16-16-16 DEPTH OUT 9280 ROT HRS. 16.0 FOOTAGE 420 AVG ft/hr 26.3 GRADE 6-6-BT-M-E HOLE DEV. 8.2 COST/FT 155 RPM 170 WOB ' 48 10 ATJ-PS11HD 8.5 18-18-18 DRILL CEMENT 75 5 DRill RATE ftlhr CORRECTED "D" EXP. SHALE DENSITY g/cc EWR Res. NO. 36 DATE Apr 15 98 TIME 00 01 P.B.U. NORTH SLOPE ALASKA 175 (TOP CMTI .88 OPEN HOLE psi ppg psi ppg psi ppg ft ft ft HYDRAUUC DATA PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min 100 FLOW RATE gal/min , 422 PRESSURE psi PO SURF I OS 'psi ANN I BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 2. ID 1 600 6X 12 4.22 1150 50/61 5 175/31 0 182 408 75 26% - 1.3 IIN2 psi at _stklmin psi at _stklmin .:= ANNULAR DATA .¡j ~ LENGTH - FT. VOLUME BBLS/FT. VELOCITY FT/MIN CRIT -VEL FT /MIN ANN-VOL BBlS .~ I DP - CSG 5 - 8.68 9061 .0489 205 335 DP - HOLE 5·8.5 .0459 "1" }:"" I DC - CSG 6 3/4- 8.68 125 .0289 347 390 ., I @ 9186 DC - HOLE 6 3/4- 8.5 .0259 PIPE DATA - 'OD-inches DRILL STRING CASING: COND SURF INTER DP HWDP DC DEPTH 110 2664 9276 5.0 5.0 6.75 @ 9186 20.0" 1 3 3/8" 95/8" LID-inches 4.276 3.0 2.81 19.12 1 2.41 5 8.681 . 'I CAP-bbls/ft .0178 .0087 .0077 .355 .1498 .0732 DISP-bbls/ft .0075 .0181 .0365 .0334 .0240 .0168 LENGTH-ft 8423 638 125 110 2664 9276 WEIGHT-Ibs/ft 19.5 49 100 94 68 47 'I REMARKS AND RECOMMENDATIONS lMW 9.5 GPM 475 JETS 3-13's 2750 PSI ftlmi = sec/std I COMPLETE SECOND STAGE CEMENT JOB. DISPLACE WITH RIG PUMPS. BUMP PLUG. PARTIAL RETURNS NOTED FOR FIRST PART OF DISPLACEMENT. NO RETURNS ON lAST 500+ STOKES. 150 BBL OF MUD LOST TO THE HOLE OVERALL. RID CMT EQUIP. FREEZE PROTECT il 9 5/8-13 3/8 ANNULUS. TEST BOP. M/U BHA ON BIT NO. 10. RIH. DRILL OUT ES CEMEMTER AT 7416. RIH. TAG CEMENT AT 9186. tBU. TEST ~ I CASING TO 3500 PSI FOR 30 MIN. DRILL ON CEMENT. WILL REDUCE PORE PRESSURE ESTIMATE AFTER DRilLING TO BASE OF KINGAK - TOP TOP OF SAG RIVER. (I I ADT JOHN PATTON 1 DEPTH 9300 fað63 TVD) OPERATION TRIP FOOTAGE 20 ( ( Spert, ·...un ~R~~~kl~NG SYSTEMS APPlED DFlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWE8T EILEEN 2-Ð1 RIG NAME RIG 8 LOC. 8EC 19 - T12N - R11E -~ OPERATOR BP EXP~ORATlON CONTRACTOR POOL AÃCTIC ALA8KA .. START DATE M.r 1098 LOGGING DATA fII I ... AYO MAX AT GAS GAS DEPTH (units) (unlta) (f._I) f1 BACKGROUND 50 175 F/LOT CONNECTION TRIP 25 9280 FLOWLINE TEMP 88 d_gre_s F CASING PORE PRESSURE 4582 pal 9.0 FRACTURE PRESSURE 7099 psi 15.8 .,." ECD 4448 psi 9.9 MUD DATA TIME ~ TYPE WEIGHT IN FUNNEL VIS. PV /vp GELS pH F Il T ICAKE API HP-HT .f Pm Pf/Mf ~ CHLORIDES ppm CALCIUM ppm , OIUWATER/SOUDS DAtL V/CUM. COST 4-16-98 KCL POLY 9.6 65 21/1 5 3/6 10.4 3.8- 1/32 8.0 .8 .1/.9 30000 120 0194/4.3 .1 DP - C80 5 - 8.68 .~ I DP - HOLE 5 - 8.5 I DC - caG 6 3/4- 8.68 DC - HOLE 6 3/4- 8.5 -r I OD-inches " ID-inches ..I CAP-bbls/ft DISP-bbls!ft I' LENGTH-ft ,". WEIGHT-Ibs/ft I DP 5.0 4.276 .0178 .0075 8443 19.5 LENGTH - FT. 9081 105 20 HWDP 5.0 3.0 .0087 .0181 638 49 NO. 37 DATE Apr 18 98 TIME 00 01 FIELD/BLOCK AREA STATE t;'¡ :14.6 D8 8.?? DFG A7 59.7 5~~ _ H^LE - 50% 81l T6TONE 9300 8URVEY DATA UTHOLO~Y 8AMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1555 4350 FaWATION PRESSURE DATA BOTTOM HOLE ppg 4054 pal 9.0 ppg ppg 7118 pal 15.8 ppg ppg 4460 pai 9.9 ppg lIT DATA BIT NO. 9 TYPE MFDSSHCR IADC CODE W/MOTOR SIZE 12.25 JETS 16-16-16-16 DEPTH OUT 9280 ROT HRS. 16.0 FOOT AGE . 420 AVG ftlhr 26.3 GRADE 6-6-BT-M-E HOLE DEV. 8.2 COST/FT 155 RPM 170 WOB 48 10 ATJ-PS11HD 8.5 18-18·18 9300 2.9 20 6.9 NA 75 50 DRILL RATE ftlhr CORRECTED "0" EXP. SHALE DENSITY g/cc EWR Re.. P.B.U. NORTH SLOPE ALASKA 7.0 1.8 OPEN HOLE pai ppg pli ppg psi ppg HYDRAUUC DATA 2. ID 1800 6X 12 4.22 PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY oal/atk 4.22 PUMP RATE atks/mln 100 FLOW RATE gal/mln 422 PRESSURE pal PO SURF I OS pal ANN I BIT plÍ JET VELOCITY ftI.ec JET IMPACT Iba BIT HP HP RATIO I HP/IN2 REDUCED 1 RATE 2 ANNlI..AR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0489 205 CRIT -VEL FT/MIN 300 ft ft ft 950 50/470 145/285 182 381 70 30% - 1.2 JIN2 pal at Itklmln - psi at Itk/min - .. ANN-YOl BBlS FEtMRKS AND RECOMMENDA1lONS 'MW 9.5 GPM 475 JETS 3-131s 2750 PSI ft/mi = sec/std ... . - I DRILL OUT FLOAT EQUIPMENT AND SHOE. CBU. DRilL 20' OF NEW FORMATION. SLOW PENETRATION RATE NOTED (7 FT/HR AVG) WITH 50,000 WOB. P08SIBLE MECHANICAL PROBLEM GETTING WEIGHT TO BIT OR POSSIBLE DAMAGE TO BIT CAUSING SLOW ROP. CIRCULATE AT 9300'. RUN LEAK OFF TEST TO 15.8 PPG. DISPLACE HOLE WITH FRESH MUD - 9.5 KCL POLY CORE FLUID. PH COMTAMINATlON FOUND IN "MUD COMING BACK FROM EXPOSURE TO CEMENT. CLEAN PITS. REPLACE SOME OF THE CONTAMINATED MUD AND TREAT. POOH. I t ADT JOHN PI\TJON .0459 .0289 347 390 .0259 388 390 ÆIE DATA DRILL STRING CASING: COND SURF INTER DC DEPTH 110 2664 9276 6.75 20.0" 1 3 3/8" 9 5/8" 2.81 19.12 12.415 8.681 .0077 .355 .1498 .0732 .0365 .0334 .0240 .0168 125 110 2664 9276 100 94 68 47 ,f I 1.1 DEPTH 93i1 (8753 TVm OPERATION TRiP FOOTAGE .91 . ( Spe~;r-Sun ~~~~~:&,~~'.!-~ING SYSTEMS NJPLED DRIWNG TEaiNOlOGY MORNING REPORT WEll NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOCo SEC 19· T12N - R11E "I' OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 ( UJGGING DATA AVG MAX AT GAS GAS DEPTH (units) (units) ('8el) BACKGROUND 250 1985 9358 CONNECTION TRIP 50 9300 FLOWLINE TEMP 95 degrees F [ 1 CASING ;...:1 PORE PRESSURE 4582 psi 9.0 FRACTURE PRESSURE 7099 psi 15.8 ] ECD 4448 pal 9.9 TIME I"~, TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH · Fll T /CAKE API HP-HT '" Pm P'IMf ,"" CHLORIDES ppm CALCIUM ppm 0Il/WATER/SOllD8 DAll Y/CUM. COST MUD DATA 4-17-98 KCl POLY 9.8 54 20/14 215 8.3 3.8- 1/32 8.3 .8 .21.9 30000 140 0(93.5/4.8 DP . CSG 5 - 8.68 DP. - HOLE 5 - 8.5 ..I' ~',.' .\~,' w.....,J DC - HOLE 6 3/4- 8.5 OO-inches IO-lnches I CAP-bbls/ft DISP-bbls/ft lENGTH-ft WE IGHT -Iba/ft DP 5.0 4.276 .0178 .0075 8641 19.5 lENGTH - FT. 9276 3 112 HWDP 5.0 3.0 .0087 .0181 638 49 NO. 38 DATE Apr 17 98 TIME 00 01 FIELD/BLOCK AREA STATE (RI 9?14.6 OS '\1' DFG A'1 ~.7 70% UMESTONÉ - 30% 8ANO/SANSTONE 9390 SURVEY DATA LITHOLOGY 8AMPlE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1565 4450 R»WA11ON PRESSURE DATA BOTTOM HOLE 4233 pli 9.0 6145 psi 13.5 4506 psi 9.9 ppg ppg ppg BIT NO. 11 TYPE ARC-425C3 IADC CODE CORE #3 SIZE 18.5 JETS TFA: .75 DEPTH OUT 9391 ROT HRS. 3.6 FOOTAGE 90 AVG ftlhr 25.0 GRADE NA HOLE DEV. C08T 1FT 420 RPM 90 WOB 10/12 ppg ppg ppg BIT DATA 10 ATJ-PS11HD 8.5 18-18-18 9300 - 9301 2.9 20 6.9 6-7-A-1-E-I-CP 8.2 75 50 DRill RATE ftlhr CORRECTED "0" EXP. SHALE DENSITY Glcc EWR Res. P.B.U. NORTH SLOPE ALASKA 40 1..03 OPEN HOLE psi ppg psi _ ppg psi ppg tlYDlWJUC DATA 2. ID 1600 6X 12 4.22 PUMPS 1. ID 1600 SIZE Inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE atka/mln 87 FLOW RATE gal/mln 367 PRESSURE pai PD SURF / OS psi ANN / BIT psi JET VELOCITY ft/lec JET IMPACT lb. BIT HP HP RATIO I HPIIN2 REDUCED 1 RATE 2 ANNUI.AR DATA VOLUME BBlSIFT. VELOCITY FTlMIN .0489 179 .0459 190 CRIT -VEL FT/MIN 285 285 It It It 1100 50/715 125/21 0 45 19% - .811N2 psi at -,tklmln pII at __tk/mln ANN-VOL BBlS .0259 337 365 PIPE DATA DRill STRING CASING: COND SURF INTER DC DEPTH 110 2684 9276 6.75 20.0' 1 3 3/8" 9 5/8" 2.81 19.12 12.415 8.681 .0077 .355 .1498 .0732 .0365 .0334 .0240 .0168 112 110 2664 9276 100 94 68 47 ÆUl-JICB AND RECOMMENDATIONS 3-13's 2750 PSI I t.MI 9.6 POOH. MfU 90' CORE BARREL ON NB #11. RIH. WASH AND REAM TO BOTTOM TO 9301. CBU. MAX GAS - 50 UNITS. START CORE. CORE NO.3 FROM 9301 - 9391'. TIGHT HOLE ON NOTED ON SECOND CONNECTION DURING CORE. AT 9391' POH INSIDE CASING. CBU. POOH. NOTE: PORE PRESSURE ESTIMATE FOR BOTTOM - 9.3 PPG IN SHUBLIK FORMATION (STARTING AT 9375). PORE PRESSURE FOR SAG l RIVER - 9.0 PPG. GOOD SHOWS AND HIGH BACKGROUND GAS READINGS lOGGED IN SAG. MAX GAS -1985 FROM 9358' ADT GPM 475 JETS JOHN PATTON ftlmi = sec/std f I DEPTH 9~;)o (8191 TVD) OPERATION bRILlING ~ fOOTAGE 39 -... OPERATOR SP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 1098 BACKGROUND CONNECTION TRIP " FLOWLINE TEMP ...,. AVG GAS (units) 125 MAX GAS (units) 600 160 100 93e1 degr.ea F CASING PORE PRESSURE 4041 pal 9.0 fRACTURE PRES8URE 1095 psi 15.8 ,.' ECD 4490 psi 10.0 IlUDI:MTA TIME ~ TYPE WEIGHT IN FUNNEL VIS. PV IYP GELS pH FIL T /CAKE API HP-HT Pm Pf/Mf ,I.. CHLORIDE8 ppm CALCIUM ppm OIL/W A TER/SOllDS DAILY/CUM. COST 4-18-98 KCL POLY 9.1 56 21/13 3{4 8.9 3.2- '/32 8.6 1.1 .15/1.05 29000 60 0/9216.4 LENGTH - FT. 9276 DP - C80 5 - 8.68 DP - HOLE 5 - 8.5 l' ') ~~ " DC - HOLE 6 3/4- 8.5 154 8peJ~~un ( DRILLING SERVICES lœGlNG SYSTEMS A Ut:IItiI tuJ81~NC. COJIw.N APPlED DFlWNG TECHNOLOOY MORNING REPORT WELL NAME NORTHWEST EILEEN 2.01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA AT DEPTH (f..1) 9427 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM 1590 4480 FIELD/BLOCK AREA STATE fRI 9314.8 08 "87 DFG A7 M DFG 40% LlME8TONÈ - 204Mt 8AND - 40% 81LTSTONE 9430 NO. 39 DATE Apr 18 98 TIME 00 01 P.B.U. NORTH SLOPE ALASKA 12 1.98 OPEN HOLE pal ppg pal ppg psi ppg tlYDfWJUC DATA 2. ID 1600 6X 12 4.22 ftlmi ft ft ft 2100 50/1375 150/525 248 556 138 25% - 2." nN2 pal at atk/mln - psi at Itk/min - ANN-VOL BBLS .0259 414 360 ...: DATA DRILL STRING CASING: COND SURF INTER DC DEPTH 110 2664 9276 6.15 20.0- 13 3/8" 9 5/8" 2.81 19.12 12.415 8.881 .0077 .355 .1498 .0732 .0365 .0334 .0240 .0168 215 110 2604 9216 100 94 68 47 FaWA110N PRESSUFE DATA BOTTOM HOLE ppg 4297 psi 9.4 ppg ppg 6167 pai 13.5 ppg ppg 4571 pal 9.9 ppg lIT DATA .. BIT NO. 11 12 TVPE ARC-425C3 ATJ-P811HD IADC CODE CORE #3 W /MOTOR SIZE 18.5 8.5 JETS TFA: .75 16-16-16 DEPTH OUT 9391 ROT HRS. 3.6 2.9 FOOTAGE 90 39 AVO, ftlhr 25.0 13.4 GRADE NA HOLE DEV. 8.7 C08T 1FT 1 -4-85-X-TD 635 RPM 90 163 (TOTAl) WOB 10/12 25135 DRILL RATE ftlhr CORRECTED "0" EXP. SHALE OEN81TY glee EWR Res. PUMPS 1. ID 1600 SIZE Inchea 6 X 12 CAPACITY gal/ark 4.22 PUMP RATE Itka/min 105 FLOW RATE gal/mln 442 PRESSURE pal PD SURF I DS psi ANN I BIT psi JET VELOCITY ft/aec JET IMPACT Ib, BITHP HP RATIO / HP/lN2 REDUCED 1 RATE 2 ANNULAR DATA VOLUME BBLSIFT. VELOCITY fT¡MIN ' CRIT -VEL FT/MIN .0489 220 270 .0459 ÆMARICS AND RECOMMENDATIONS 3-13·s 3000 PSI J tmI 9.7 POOH. LAY DOWN CORE #3. RECOVER 100% Of CORE. DECISION MADE TO DRILL TO TO. M/U NEW BHA WITH MOTOR ON BIT NO. 12. RIH. REAM AND LOG THROUGH CORED SECTION OF THE HOLE. MAX GAS FROM REAMING - 160 UNITS. DRILL AHEAD. MAX GAG PAST r 24 HOURS - 600 UNITS FROM APPARENT FRACTURE AT 9427'. RAISE PORE PRESSURE ESTIMATE TO 9.4 PPG BASED ON CORRELATION b ,I DATA AND GAS READINGS. I OP HWDP J OD-inches 5.0 5.0 ID-inches 4.276 3.0 CAP-bbls/ft .0178 .0081 DISP-bbla/ft .0015 .0181 lENGTH·ft 8577 638 WEIGHT-Iba/ft 19.5 49 GPM 475 JETS , I to- I ADT JOHN P,ATTON = sec/std ~ 974?17 08 o.'\? DfG A'1 84,'1 QfG 80% CONGLOMÉRÄTlè'8ANDSfoNÉ -1mf1SILTSONE 9815 1 (" { spen ,,-sun DRILLING .~RVtCE8 It:JGt3/NG. SYSTEMS A fItIa:t1 tI.JObltb tIC. ~N« APPLED DRlWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-Ð1 RIO NAME RIG 8 LOC. SEC 18 - T12N - R11E I. DEPTH 981~ (9175 TVD) OPERATION DRILLING FOOTAGE 385 1 OPERATOR BP EXPLORATION .' CONTRACTOR POOL ARCTIC ALASKA START DATE M...10 98 ( IDBGING DATA AVG MAX AT GAS GAS DEPTH (units) (units) (feel) BACKGROUND 20 628 9587 CONNECTION NONF 607 9516 TRIP 71 9815 fLOWLINE TEMP 110 degree. F SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM I. 1. CASING PORE PRESSURE 4041 psi 9.0 fRACTURE PRESSURE 7095 pal 15.~ I ECD ....110 pal 10.0 1e50 4700 FORMATION PFESSUFE DATA BOTTOM HOLE ppg 4437 pal 9.3 ppg ppg 8441 psi 13.5 PPO ppg 4771 pal 10.0 ppg lIT DATA MUD DATA TIME I TYPE WEIGHT IN · fUNNEL VIS. PV /VP I GELS pH . FIL T/CAKE API HP-HT BIT NO. 11 TYPE ARC-425C3 IADC CODE CORE #3 SIZE 18.5 JETS TFA: .75 DEPTH OUT 9391 ROT HRS. 3.6 FOOTAGE 90 AVO ftlhr 25.0 GRADE 1-4-85-X-I-TD HOLE DEV. 8.7 COST 1fT 420 RPM 90 WOB 10112 12 ATJ-PS11HD W IMOTOR 8.5 16-16-16 9815 19.5 424 21.7 NA 5.4 168 170 (TOTAl) 25 4-18-98 KCL POLY 9.7 56 21/13 3/4 8.9 3.2- 1/32 8.6 1.1 .15/1.05 .29000 60 0/92/6.4 Pm PflM' ... CHLORIDES ppm CALCIUM ppm I" OIL/WATER/SOUDS . DAIL V/CUM. COST ANNU.AR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0489 218 " LENGTH - FT. 9276 DP - CSO 5 - 8.68 DP - HOLE .0459 232 5 - 8.5 324 ~~,:,:,,' , " . : L.:.r NO. 40 DATE Apr 19 98 TIME 00 0' FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA DRILL RATE ftlhr 30 CORRECTED "0" EXP. 1.5? SHALE DENSITY ø/ee EWR Re.. OPEN HOLE pal ppo pal ppg pal ppg HYDfWJUC DATA 2. ID 1600 6X 12 4.22 It ft It PUMPS 1. 10 1600 81ZE Inche. 6 X 12 CAPACITY gal/atk 4.22 PUMP RATE atka/mln 107 FLOW RATE gal/mln 447 PRESSURE pal PO SURF I OS psi ANN / BIT psi JET VELOCITY ftlsec JET IMPACT Ib, BIT HP HP RATIO I HP/lN2 REDUCED 1 RATE 2 2200 50/1480 150/520 244 553 135 23% - 2.4 IIN2 pai at -,tklmln psi at stklmln - CRIT -VEL fT/MIN 270 ANN·VOL BBLS 270 DC - HOLE 6 3/4- 8.5 215 .0259 411 380 NJf: DATA DRILL STRING CASING: COND SURF INTER DP HWDP DC DEPTH 110 2684 9276 [ OD-inches 5.0 5.0 6.75 20. ()I' 13 3/81 9 5/81 10 -Inchea 4.276 3.0 2.81 19.12 12.415 8.681 CAP·bbls!ft .0178 .0087 .0077 .355 .1498 .0732 DISP-bbla/ft .0075 .0181 .0365 .0334 .0240 .0168 LENGTH-ft 8962 638 215 110 2664 9276 WEIGHT -Ibs/ft 19.5 49 100 94 68 47 1 fEMNICS AND RECOMMENDATIONS MW 9.7 GPM 475 JETS 3-13'9 3000 PSI ftlml = see/std DRILL AHEAD. CONNECTION GAS READINGS RECORDED WHILE DRILLING IN THE SHUBLIK. DRILL TO LOWER TARGET . IVISHAK SANDSTONE. I, MODERATELV lOW GAS READINGS FROM 9575-9630. LOW GAS READINGS BELOW THIS INTERVAL DRILL TO 9815· TOTAl DEPTH FOR NWE #2-01. PORE PRESSURE ESTIMATE FOR THE BOnOM OF THE HOLE - 9.3 PPG. CBU WITH SWEEP. POH 6 STANDS. RIH. CBU WITH SWEEP. MAX TRIP GAS - 71 UNITS. POOH. ADT ~OHN PATION f spel~:I-sun DRILLING SERVICES lOGGING SYSTE"US A ['.ŒSSER N)USTFES NC. CONPÞHf I DEPTH 981 5 (9175 TVD) OPERA TION MDT LOG FOOT AGE 0 I OPERATOR BP EXPLORATION CONTRACTOR POOL ARCTIC ALASKA START DATE Mar 10 98 I AVG MAX AT GAS GAS DEPTH (units) (units) (feet) BACKGROUND 0 I CONNECTION TRIP 71 9815 FLOWLINE TEMP 90 degrees F 1 CASING PORE PRESSURE 4041 psi 9.0 FRACTURE PRESSURE 7095 psi 15.8 .I ECD 4490 psi 10.0 MUD DATA TIME 4-19-98 I TYPE KCL POLY WEIGHT IN 9.7 FUNNEL VIS. 48 PV /YP 20/11 I GELS 2/5 pH 9.0 FIL T/CAKE API 2.8- 1/32 HP-HT 8.3 I Pm 1.1 Pf/Mf .1 0/1 .1 CHLORIDES ppm 29000 CALCIUM ppm 80 I Oil/WATER/SOLIDS 0/92/6.4 DAILY/CUM. COST [ LENGTH - FT. DP - CSG 5 - 8.68 9276 DP - HOLE 5 - 8.5 324 APPUED DRIWNG TECHNOLOGY MORNING REPORT WELL NAME NORTHWEST EILEEN 2-01 RIG NAME RIG 8 LOC. SEC 19 - T12N - R11E LOGGING DATA NO. 41 DATE Apr 20 98 TIME 0001 FIELD/BLOCK AREA STATE P.B.U. NORTH SLOPE ALASKA 1650 4700 FORMA11ON PRESSURE DATA BOTTOM HOLE ppg 4437 psi 9.3 ppg ppg 6441 psi 13.5 ppg ppg 4771 psi 10.0 ppg BIT DATA @ 9742.17 OS 5.42DEG AZ 64.81 DEG 90% CONGLOMERATIC SANDSTONE -10% SILTSONE 9815 12 ATJ-PS11HD W IMOTOR 8.5 16-16-16 9815 19.5 424 21.7 6-4-CT -A-E-1 5.4 168 1 70 (TOTAL) 25 DRILL RATE ft/hr 30 CORRECTED "D" EXP. 1.52 SHALE DENSITY glee EWR Res. OPEN HOLE psi ppg psi ppg psi ppg ft ft ft SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM BIT NO. 11 TYPE ARC-425C3 IADC CODE CORE #3 SIZE 18.5 JETS TFA: .75 DEPTH OUT 9391 ROT HRS. 3.6 FOOTAGE 90 AVG ft/hr 25.0 GRADE 1-4-85-X-I-TD HOLE DEV. 8.7 COST/FT 420 R PM 90 W 0 B 1 0/12 HYDRAUUC DATA 2. ID 1 600 6 X 12 4.22 PUMPS 1. ID 1600 SIZE inches 6 X 12 CAPACITY gal/stk 4.22 PUMP RATE stks/min FLOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT Ibs BITHP HP RATIO / HP/IN2 REDUCED 1 RATE 2 STATIC psi at _stk/min psi at ~tk/min ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0489 .0459 CRIT -VEL FT/MIN ANN-VOL BBLS DC - HOLE 6 3/4- 8.5 215 .0259 J PIPE DATA DRILL STRING CASING: COND SURF INTER DP HWDP DC DEPTH 110 2664 9276 OO-inches 5.0 5.0 6.75 20.0" 1 3 3/8' 9 5/8" IO-inches 4.276 3.0 2.81 19.12 12.415 8.681 CAP -bbls/ft .0178 .0087 .0077 .355 .1498 .0732 OISP-bbls/ft .0075 .0181 .0365 .0334 .0240 .0168 I LENGTH-ft 8962 638 215 110 2664 9276 WEIGHT-Ibs/ft 19.5 49 100 94 68 47 FEMARKS AND RECOMMENDATIONS .. MW 9.7 GPM 475 JETS 3-13's 3000 PSI ft/mi sec/std ~ = POOH. P/U MDT TOOL. MAKE UP ON DRILL PIPE. RIH. RUN FLUID TEST ON SPECIFIC ZONES. NO GAS READINGS PAST 24 HOURS. FINAL AOT REPORT. WILL COMPLETE UNIT RIG DOWN LATER TODAY. I ' I 'ADT JOHN PATTON ) ) ) BP EXPLORATION, Alaska NW EILEEN LOG DATA Date: Trans# 06-10-98 89193 Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 _ Sw Name Log Type Rec Type Ree Date Comments S -2 . o:,~ NWE2-01 MUDLOG REP 20-Apr-98 FINAL ADT WELL SUMMARY - BOUND REPORT 05-Mar-98 FINAL ADT WELL SUMMARY - BOUND REPORT Q NWE1-01 MUDLOG REP \~'0~ Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ARca - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips - Paul Robertson DNR - Tim Ryherd AOGCC - Howard Oakland BP - Brett Chambers J~~ (p! I 0/<12 Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 ) ) ) BP EXPLORATION, Alaska ,/ory .,,( /' 1::; ~ NW EILEEN 'V' LOG DATA Date: Trans# 06-08-98 89186 Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 c¡ :g. 0 3>~- Sw Name Log Type Rec Type NWE2-01 CNL OH NWE2-01 DSI OH NWE2-01 SS TVD OH NWE2-01 CNL OH NWE2-01 BOREHOLE OH PROFILE NWE2-01 MDT OH NWE2-01 AIT TAPE NWE2-01 AIT OH 1 NWE2-01 CMR OH NWE2-01 MCFL OH NWE2-01 CST OH Rec Date Comments 02-Apr-98 PLATFORM EXPRESS COMPENSATED NEUTRON 02-Apr-98 DIPOLE SHEAR SONIC IMAGER COMPRESSIONAL AND SHEAR 02-Apr-98 SUB SEA TRUE VERTICLE DEPTH 02-Apr-98 PLATFORM EXPRESS THREE DETECTOR DENSITY COMPENSATED NEUTRON 02-Apr-98 BOREHOLE PROFILE 19-Apr-98 MODULAR FORMATION DYNAMICS TESTER 03-Apr-98 PEX/AITI DSII FMI, CMR; MAIN AND REPEAT 02-Apr-98 PLATFORM EXPRESS ARRAY INDUCTION IMAGER 30-Mar-98 PLATFORM EXPRESS MICRO CYLINDRICALLY FOCUSED LOG 02-Apr-98 COMBINABLE MAGNETIC RESONANCE TOOL Please sign and return one copy of this transmittal letter. 02-Apr-98 SIDEWALL CORE RECORD Thank-you, N adene Reichert Petrotechnical Data Center ARCO· Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips· Paul Robertson DNR - Tim Ryherd AOGCC - Howard Oakland ~~~ G /11 qg Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 ) ) BP EXPLORATION, Alaska , , I~. :"' ~..,.... \"~ C: :.~. NWEILEEN DIRECTIONAL DATA ) "'uJ]j rmrmllil':. Date: 6/3/98 Trans# 89171 Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4944. DIRECTIONAL SURVEY ~~~, O~~' ~w Name I ype uate Co (jomments NW1::2-01 MWU 03/18/98 SPI::RKY MWLJ SUKVI::Y KI:::POk I W/UISC Please si~n and re~Y.ll\ one copy,pf this transmittal letter. Thank-rU, ")" ' /~; v' ,/~ ~t¿ / ~/;/; ~~~¿:/ , " ¿- 7 . è- '------ r---- Gary B 9feble -', , c~ "'-c Jv~, ~, Petrotechnical Data Center ~~ ~ STATE REPORTS ARCO -G. Van Kooten DNR - T. Ryherd EXXON -C. Riley Phillips- P. Robertson Chevron- G. Forstaff Mobil- F. Banar Bret Chambers DIRECTIONAL ARCO -G. Van Kooten DNR - T. Ryherd EXXON -C. Riley Phillips- P. Robertso Chevron- G.Forstaff Mobil- F. Banar AOGCC- H. Okland Bret Chambers Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 I~""\:':"""-'; :"'(~ ',:; ::......,',:;."..;;;~'}/ I ï ) ) ) ¡® .. BP EXPLORATION, Alaska Date: Trans# 06-02-98 89169 NW EILEEN LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 ..p;:.- ~ ~Ù' \ - -ß 5D S- Sw Name Log Type Ree Ree Date Meas Depth Meas Depth Comments Type Top Base '·l'8 . 0 ~S' NWE2-01 MWD TAPE 18-Apr-98 85. 9,782. MWD MPT GRC EWR CNP RHOS ROP t DGR/EWR NWE2-01 MWD OH 19-Apr-98 9,280. 9,815. MWD DGR CNO SLD DGR/CNQ NWE2-01 MWD OH 19-Apr-98 8,643. 9,175. TVD - MWD DGR CNO SLD DGR/CNO NWE2-01 MWD OH 19-Apr-98 110. 9,815. MWD ROP DGR EWR4 DGR/EWR V NWE2-01 MWD OH 19-Apr-98 110. 9,175. TVD - MWD DGR EWR4 DGR/EWR Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips - Paul Robertson DNR - Tim Ryherd AOGCC - Howard Oakland &~ ~ /õ!J /9 <g Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 ) BP EXPLORATION, Alaska NW EILEEN LOG DATA ...;;.4·' '~~l~: r:~ ~i:':~' ..~ ,. Date: Trans# 05-01-98 89070 Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 qß. ass- Sw Name Rec Type Rec Date Meas Depth Top Meas Depth Base Comments ¥ NWE1-01A OH 07-Apr-98 5,500. 9,070. COMBINATION ENGINEERING LOG NWE1-01A OH 07-Apr-98 5,500. 9,070. COMBINATION MUD LOG q-g.-O"&S" NWE2-01 OH 11-Mar-98 110. 9,815. COMBINATION MUD LOG ~ NWE2-01 OH 11-Mar-98 110. 9,815. ENGINEERING LOG ~E.L\NE.ß c~'-'i \' -=- l; Lo~,,:::> Kc..v&- Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ~~~ ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips - Paul Robertson DNR - Tim Ryherd os-I D-I/q 1> Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 ) ) , .. R1LAB J_ ..] Core Laboratories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 To: Alaska Oil & Gas Conservation CommissioN 3001 Porcupine Drive Anchorage, Alaska 99501 Date: ~-?3-/r qf---1! ¿; ¡:; 0í~ ,~~ t--.:u,.. /F/ð/"f? Well Name: lJ w £ Number of Samples: z.- -0/ 9/, j-D ' .....3 Contact: ,S .:...:&> IT %l.." /~ /~ JY7 ,- 3)-Y I Description of Material: /',/", .ft-3 Depths: <---D " '"- Core Chip Samples /300. (';/0 -. <J 3? I rù Sent By: C."r.e... /_t- ?~ L~./) . (/~-: It.' . ~:: ~~.. ...l ;'::: ~ .' .: Received By: ,n~_) '~' 3 - :~aç ;1~~(;J ~ },~! ¿~:.:iL: \jG:';~, \,;cm;r¡;~w""C ;Ci:~~;3C:r' q~ (j IJ- C{.) 'ì 0 ) ) ~ :ULAB Core Laboratories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage. Alaska 99518 --"" qß--'~ 11 To: Alaska Oil & Gas Conservation CommissioN 3001 Porcupine Drive Anchorage, Alaska 99501 Date: y- -¿ ]-- 7 f ý)oIx ff {6 t~ Well Name: IV ~ I~' ::<. -ð I ,- a ," c:_~ ¿Y (... j f<. Contact: S c-.,:. Tf. 2~.Çi P/ 2J ')' ßZ- ¡<ct.", ~ 1(...-.. 3 5'9 - J )'V I Core Chip Samples Number of Samples: Description of Material: ~/-¿- .Þf Z 7G~J 'loo }O&h,OO 70bO. s··....o 70 '1'1. $-0 7 (j ~ tic ( -to, d, ( ~11.. I 70' c). Depths: ~" ~ zI / Sent By: ¿,,:C,r<- L¿ ?~Ø ~ .. ,_l -~ ~.~ ,,¡j, ~~ ~,~~.J ;~,'...,. ~ :;" ~~ ;~'.:!':. ì () 6',/~- - 70 q'f, c{ Received By: 'JR o"ì -, "('\('\Q :) \- , (_.: t :.; ;.' C:f , ,',_., _ . '.., "" "",mr.,.(,~..,,, ;"'~~~1 ,~.I.:. '....'.,,~~.. "':'\:"', v"m/!hl..,..,\...I! ',~c,...4.1''¡'t..-..,.. . ."tiH ~~ ....,"'--.. "'..... , ,~C~1,!"'(~C~ \ 'Î f MEMORANDUM State of Alaska ~Alaska Oil and Gas Conservation Commission TO: David Johns , DATE: April 21, 1998 Chairman ,- THRU: Blair Wondzell, .¡¡ßc..ßaµ... P. I. Supervisor tJJ1ò FROM: Chuck Scheve, G-5 Petroleum Inspector FILE NO: n99kdufe.doc SUBJECT: Open Hole Cement plug N.W.E. 2-01 PTD #98-0035 Tuesdav. April 21. 1998: I witnessed the tag for verification of placement of the Open Hole Cement plug in BPXs N.W.E.2-01 well. The well was drilled to TD of 9900' and 9 5/8" casing shoe was at 9276'. A cement plug was set from TD to an estimated top 8970'. After waiting 6 hours the plug was tagged at a depth of 9005' with 20 thousand pounds drill pipe weight while circulating at 3 bbls per minute. SUMMARY: The tag I witnessed on BPXs N.W.E 2-01 Open Hole plug verified proper placement and integrity of the cement CONFIDENTIAL , ~. ~ ~ 13:27 FAX 907 564 5193 BP EXPLORATION 141 001 ) ) 98 -o3S- ® BP EXPLORATION BP Exploration (Als$ka} Inc. 9QQ east Ben90n eOufevard P.O. Box 196612 Anèhorage. AI~ska 99519-6612 (907) 581·5111 ~ DATE:.. iflJ 11$',. TO: TELECOPY Name: P(ttll.. Wð~'ZiI/ Company: AcG:.. CC Location: It Nc!,..ø/ltï( Fax Nwnber: 'ït"'7Çt¡'Ç)- ~~~~\~t~\\~\. FROM: Name: c;.J~í vveSI Department: s s.D Location: Mcì-at ^'f- Fax Number: 5b'{-S 1'7 :3 5"b ¥" YSClŠ ( tw ) ;J.Y3-0],77 CN) J-~5"I/ìc (p~) 6111 ìJ1.. } we.. ~ - A ~. f1e._ £/03 ~ ~'. ~.-Ø <f ~ d- ~ # ~ ~ .-Ø:h. VJdfl f/ cJ.-u.VI 1þ3 pI,)/¡~. 5..tsfNSI"'N f{(3èp~ ~ -Ir;-- SiltJ/frldAi fiftlefrAN . 1ÃÆN~S Jr4 ( .3 . PAGES TO FQLLOW) 04/17/98 13:27 FAX 907 564 5193 BP EXPLORATION 141 002 ) ) North West Eileen 2..01 Approved Drilling Permit #98-35 API #50-029..22866 t\\\\~\\)t~\\~\. Well Suspension Procedure "Shut Down of Well Operations", 20AAC 25.072 QVERVIEW North West Eileen 2-01 was drilled as a Kupamk, Sag~ and Ivishak. exploratory well from an ice pad located adjacent to the MiI ne Point Road. Due to early warming weather trends on the north slope, the condìLion of the ice pad is quickly deteriorating thus necessitating the need to reduce 'the scope of the North West EiJeen 2-01 well during the current ice season. Current wellbore conditions consist of 9-5/8" 47# L-80 NSCC casing set at 9276'md to surface; thè casing was c~mented from 9276' -8276'md with 89.7 bbls of 15.8 ppg cement and also froln 7418'..26641md with 524 bbls of 13.1 ppg cement. To date an additional 91 ~of 8-112" open hole has been drilled below the casing shoe with intentions to drill an additional 509' to a TD of 990Q'md. The following outlines the procedure for suspension of the well for planned re-entry in winter 1998/99 drilling season. C1JRRE~T CONDITIONS Open Hole Interval: Now: 9391 ~rn.d - 9276'md - 8-112" dialneter Plan: 9900~md - 9276'md ~ 8-1I2" diameter Cased Hole Interval: 9276'MD - 0' --~- 9-5/8" 47#/ft L-80 NSCC Cern,entcd: 9276'md - 8276'Ind with 89.7 bbls of 15.8 ppg 7418'md - 2664'rnd with 524 bbls of 13.1 ppg Existing Drilling Fluid: 9.6 ppg 6% KCL driHing mud PROCEDURE: 1. COlnplete drilling the 8-112" interval with MWD/GRlRESIDENINUE tools to a TD of -9900'md (the actual TD location will be chosen at 150'm.d below the owe as picked with the LWD data). 2. Short trip and Ci.rculate and condition the hole for logs, POOH. 3. PU Schlumberger MDT tool and DPC log across the Sag and Ivíshak intervals, POOH. 4. Notify AOGCC Representative of intent to begi.n plugging operations. PU 2000' of 3-112" tubi11g '~stinger" on 5" driB pipe and trip in bole to TD. Circulate 150% of hole volume to insure clean conditions. 5. Pump 10 bbls of freshwater, test lines to 3000 psi, continue with 20 bbls of fresh water spacer. 04/17/98 13:28 FAX 907 564 5193 BP EXPLORATION f4I 003 ') l ) 6. Pump 282 sx (59 bbls) of Class G + additives at ] 5.8 ppg and 1.16 ft3/sx yield (assumes open hole volume + 30% excess + 200' of cement within 9-5/8" casing) 7. Displace with KCI mud at a rnaxhnum rate (6-7 bprn). UnderdispIace by 1 bbI in order to pull dry DP. 8. POOH slowly (I stand per minute) until pipe clears the potential cement top. Stop at 8900'md and reverse circulate to clei.U' stinger and drill pipe of residual cement. 9. woe. RIH and tag top ùfplug, record t~4epth. Pressure test plug to 3000 psi. , 10. POOH laying down drill pipe. Rill wi~,?-1I2" (~tinger). Makè up tubing hanger on top. Land hanger. Test hanger and set BPV. ND BOPE and NU tubing head adapter and full bore valve ("dry-hole tree"). 11. Displace top 2000' well bore to freeze protect. 12. RDMO the ice pad location. ~7ù¥~ Greg West I Ops. Drilling Engineer C-:--<~.'~ ~ .....,.~ Da.n Stone Dan Stone Sr. Drilling Engineer DrIg. Superintendent ..t~r" b..,,: ¿J... N'~ m $ . ... , . ;\\~\. , .', 'y \\ \'r ~ \;~\\\\ \)" 04/17/98 13:28 FAX 907 564 5193 j' Sag Top @ 9326'md BP EXPLORATION 141 004 N, .t 2~01 Suspension Pro~1 Jm Depths are listed as MDffVDrkb tfm!\; :::;;;;i;¡~(~¡~~~j' I 20· Condu~or Casing @ 110' /110' ::,:,,\':9:::';11 :::,:',,0:,:; ::",:;':i:,;:: ,~~I Cement to surface ,::,:~,~;",; :-:,::~,,:, ',!::,"",,; ~:: ~ '·af : tI)." , 11 g~ -- '.. . "...-= ~@~ t_~:.=-~::.:·~_:·~ --"" '1" .. ~I] "-'-- "'1t"' ", .:.:.:..-...;: ~.:~ ~:',. .,>~:,~,., '~ lJ Top of Stage 2 Cement (13.1 ppg) ~,.' ~~",7,:"'-:::""~1 @ 2664'/2664' -"','" t .~~"'t' ~.,., ,:.,' :~\ .~::' "~ -'''''''''~ -""'-': ~.,. .".~ ,...- =--''''', 'of" J. ' " ': 41 =-" ,:,,," '~5-: ,:::." .,::: ~..:'".. ..',:.=: 'I '--:-:= -', -",..- -.. ~:':":'" .,:::= I~,.;.;" ·····:·~=···~I TD @ 9900'/9150' Diesel to 2000'md in 13-3/8" x 9-5/8" annulus and within 7" 2000' of 3-1/2" tubing st;nger 13-3/8", 68 #/ft, L-80 Surf Csg @ 2664'/2664' Cement to surface L\~\:~'\\~\' ~\\\\\ . ES Cementer Located @ 7418'/6918' Top of Stage 1 Cement 15.8 ppg @ 8276'/7688' 9-5/8", 47#/ft~ L-80 NSCC Csg @9276'md'/8640' I:. f.A ) STATE OF ALASKA ) ALASKA \......L.. AND GAS CONSERVATION COrvllvllSSION APPLICATION FOR SUNDRY APPROVAL CONFIDENTIAL 1. Type of Request: 0 Abandon ~ Suspend r:2.J Plugging 0 Time Extension 0 Perforate o Alter Casing {] Repair Well 0 Pull Tubing 0 Variance 0 Other o Change Approved Program §4.0peration Shutdown 0 Re-Enter Suspended Well 0 Stimulate 14. Estimated date for commencing operation April 19, 1998 16. If proposal was verbally approved B/~'r ~",dc.~(\ LI/trl?8 N"ame of approver Date approved Contact Engineer Name/Number: Greg West, 564-4803 Pgr275-1170, Hm243-0379 Prepared By Name/Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ---' A. Dan Stone ~-.......,. - .2/ ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' NSL, 4553' EWL, SEC. 19, T12N, R11 E At top of productive interval N/A At effective depth 2642' NSL,435' EWL, SEC. 20,T12N, R11E At total depth 2642' NSL, 4ª5' EWL, SEC.^20, T12N^, R,1,,1yE 12. Present well condition summary 5. Type of well: D Development [ZI Exploratory D Stratigraphic D Service Total depth: measured true vertical Effective depth: measured true vertical 9900 feet Plugs (measured) 9150 feet 9900 feet Junk (measured) 9150 feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented 110' 2626' 9248' 20" 13-3/8" 9-518" 260 sx Arcticset (Approx.) 1404 sx Coldset III, 473 sx Class 'G' 430 sx Class 'G', 1500 sx Class 'G' Perforation depth: measured N/A true vertical NI A Tubing (size, grade, and measured depth) N/A OR~:G~NAl Packers and SSSV (type and measured depth) NI A 13. Attachments [ZI Description summary of proposal D Detailed operations program 6. Datum Elevation (DF or KB) KBE = 74.1 AMSL 7. Unit or Property Name Prudhoe Bay Unit , . .w. 8. Well Number NWE 2-01 9. Permit Number 98-35/398-071 10. API Number 50-029-22866 11. Field and Pool Prudhoe Bay Field / Kuparuk River Oil Pool & ~rudhoe B~y Pool MD TVD 110' 2664' 9276' 110' 2664' 8640' CONFO';NTIA _ RVi':B':IVJB D D BOP sk~f1h 1 "(" 1998 AlfsRa DB A Gas C.ons. CiJIlm\s , . Krfclioragtt [ZIOil DGas 15. Status of well classifications as: D Suspended Title Engineering Supervisor Commission Use Only Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- ¿¡ ð-r Service Conditions of Approval: Approved by order of the Commission Form 1 0-403 Rev. 06/15/88 Ong""'" ;::,0 By David W. Joi111ston Terrie Hubble, 564-4628 Date '"f( 171 q , I Approval No. 398 -1 Ó ( Commissioner Date ~ Submit In TriPlicat~ ) }. North West Eileen 2-01 Approved Drilling Permit #98-35 API #50-029-22866 Well Suspension Procedure "Shut Down of Well Operations", 20AA C 25.072 OVERVIEW North West Eileen 2-01 was drilled as a Kuparuk, Sag, and Ivishak exploratory well from an ice pad located adjacent to the Milne Point Road. Due to early warming weather trends on the north slope, the condition of the ice pad is quickly deteriorating thus necessitating the need to reduce the scope of the N orth West Eileen 2-01 well during the current ice season. Current well bore conditions consist of 9-5/8" 47# L-80 NSCC casing set at 9276'md to surface; the casing was cemented from 9276' -8276'md with 89.7 bbls of 15.8 ppg cement and also from 7418' -2664'md with 524 bbls of 13.1 ppg cement. To date an additional 91' of 8-1/2" open hole has been drilled below the casing shoe with intentions to drill an additional 509' to a TD of 9900'md. The following outlines the procedure for suspension of the well for planned re-entry in winter 1998/99 drilling season. CURRENT CONDITIONS Open Hole Interval: Now: 9391 'md - 9276'md - 8-1/2" diameter Plan: 9900'md - 9276'md - 8-1/2" diameter Cased Hole Interval: 9276'MD - 0' ---- 9-5/8" 47#/ft L-80 NSCC Cemented: 9276'md - 8276'md with 89.7 bbls of 15.8 ppg 7418'md - 2664'md with 524 bbls of 13.1 ppg Existing Drilling Fluid: 9.6 ppg 6% KCL drilling mud PROCEDURE: 1. Complete drilling the 8-1/2" interval with MWD/GR/RES/DEN/NUE tools to a TD of -9900'md (the actual TD location will be chosen at 150'md below the OWC as picked with the L WD data). 2. Short trip and Circulate and condition the hole for logs, POOH. 3. PU Schlumberger MDT tool and DPC log across the Sag and Ivishak intervals, POOH. 4. Notify AOGCC Representative of intent to begin plugging operations. PU 2000' of 3-1/2" tubing "stinger" on 5" drill pipe and trip in hole to TD. Circulate 150% of hole volume to insure clean conditions. I)~I' .1:'a:rl'\~/ilü D 5. Pump 10 bbls of freshwater, test lines to 3000 psi, continue with 20 bbls dI:~ '. :.Il' ;.V.; D water spacer. ,APR 1 j 1998 ålISRa Ð.ü " Gas C.ons. C.Qll\m\s~ , I' rùíc1iOI'âg-Ø ) ') 6. Pump 282 sx (59 bbls) of Class G + additives at 15.8 ppg and 1.16 ft3/sx yield (assumes open hole volume + 30% excess + 200' of cement within 9-5/8" casing) 7. Displace with KCI mud at a maximum rate (6-7 bpm). Underdisplace by 1 bbl in order to pull dry DP. 8. POOH slowly (1 stand per minute) until pipe clears the potential cement top. Stop at 8900'md and reverse circulate to clear stinger and drill pipe of residual cement. 9. WOC for four hours. Rill and tag top of plug, record tag depth (cement will have -500psi strength after waiting four hourslooo' 10. POOH laying down drill pipe. Rill witliA3-l/2" (stinger). Make up tubing hanger on top. Land hanger. Test hanger and set BPV. ND BOPE and NU tubing head adapter and full bore valve ("dry-hole tree"). 11. Displace top 2000' well bore to freeze protect. 12. RDMO the ice pad location. {~. Pesfttrf {¡Jtl/0piffrh'o,¡s #(;¡re ~ Iqs! c!Æj of r1~rd.. /111- ,I..-. /OJf1r:tJl; L · 17 c¡ft c:::::;>_ __. .;?J:-.~ c:;:::>- "P"'I. _ ~ Greg West Dan Stone Dan Stone Ops. Drilling Engineer Sr. Drilling Engineer Drlg. Superintendent he" 1)G\.;.q \I ~ ~ s R,':Bli! E I V: E D }\PR 1 7 1998 ålasRa Oü A Gas C.O.os. commis; \ I ~cfiorag' Sag Top @ 9326'md N\ È 2-01 Suspension Prt_)am Depths are listed as MDffVDrkb ..41 I ~~~:;:~:~:~:~- :~:~:~:~~~:~: ~:: !¡~I~ 20" Conductor Casing @ 110' 1 110' 'I Cement to surface , ~ I~:: II ~:::::: :~~~:':~~i~;:~:::; 9-5/8" annulus and within 7" If 13-318",68 #/ft, L-80 Surf Csg @ 2664'/2664' _:_:_:_:_:_:_ Cement to su rface ::;¡;¡;¡;¡¡: Jit -:4-:-:-:-:- ::~: ~::: ~--- ·1 Top of Stage 2 Cement (13. 1 ppg) !~al @ 2664'/2664' IIÌIÌIiIIÎIIÌiI ..41 Cn O-J ( ) C) ([ ) ^ C) I l J - \ -- rÐ --:.. ~, n ~\~\:~\\~\, ,,\\\\\ ES Cementer Located @ 7418'/6918' - -:::~: ¡¡!I --- Ð~:~ I- -, !!2! ~ Top of Stage 1 Cement 15.8 ppg @ 8276'/7688' - 9-5/8", 47#/ft, L-80 NSCC Csg @9276'md'/8640' fj~'G¡a]j'I'V' '~D ~1Ii\!, IJ: '., ; C t,PR 1 7 1998 AlfsRa on & Gas C.ons. C.oj\1m\s- ,,"oooragø TO @ 9900'/9150' ) ) ~~ ( ;, \"",. ' ) ...."...._~ sper-r-v-sun C R I L.L.I N t:i 5 e R V I c: E 5 Contact No. NWE 2-01 #12 To: State of Alaska (AOGCC) 3001 Porcupine Drive ATTN: Lori Taylor J\nchorage,AJC 99501 ~ Q8..0JJ '-1~q¡ From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G J\nchorage,AJC 99518-1654 'JI,-~ Lðtf Çl~ Contents: Washed & Dried From: BP Exploration (Alaska) Inc. NW Eileen 2-01 API #50-029-22866-00 Prudhoe Bay, Alaska Shipment Includes: Process Depth Start 120/150 Process Depth End 1080 / 1110 Process Date Start 03/28/98 Process Date End 04/01/98 Total Number of Samples Included in this Shipment 33 Shipment Number S-008-028 Comment: 30? samples 5631 Silverado Way, Unit G, Anchorage AK 99518-1654· (907)563-3256· Fax (907)563-7252 A Dresser Industries, Inc. Company ') ) (;3~') , ) '\"" -- / ",.,.....~~ SpSr'r'v-sun CRIL.L.ING SERVices Contact No. NWE 2-01 #12 To: State of Alaska (AOGCC) 3001 Porcupine Drive ATTN: Lori Taylor PuGchorage,AJe 99501 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G PuGchorage,AJe 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. NW Eileen 2-01 API #50-029-22866-00 Prudhoe Bay, Alaska Shipment Includes: Process Depth Start 2010/2040 Process Depth End 2880/2910 Process Date Start 04/01/98 Process Date End 04/03/98 Total Number of Samples Included in this Shipment 30 Shipment Number S-008-028 Comment: 30' samples 5631 Silverado Way, Unit G, Anchorage AK 99518-1654· (907)563-3256 · Fax. (907)563-7252 A Dresser Industries, Inc. Company ') ) spar--r--v-sun C R I L.L.I N 13 5i e R V I c: E 5i Contact No. NWE 2-01 #12 To: State of Alaska (AOGCC) 3001 Porcupine Drive A TTN: Lori Taylor Au1chorage,AJe 99501 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #0 Au1chorage,AJe 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. NW Eileen 2-01 API #50;.029-22866-00 Prudhoe Bay, Alaska Shipment Includes: Process Depth Start 5790/5820 Process Depth End 6720/6750 Process Date Start 04/09/98 Process Date End 04/13/98 Total Number of Samples Included in this Shipment 32 Shipment Number S-008-028 Comment: 30' samples 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company '-7) ,( ("" r-? . "" ( ./ "'-----' } J ') ) c~o sper'r'v-sun C R I 1..1..1 N t:i 5 E R VI c: E 5 Contact No. NWE 2-01 #12 To: State of Alaska (AOGCC) 3001 Porcupine Drive ATTN: Lori Taylor Pulchorage,AJe 99501 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Þu1chorage,AJe 99518-1654 Contents: Washed & Dried From: BP Exploration (Alaska) Inc. NW Eileen 2-01 API #50-029-22866-00 Prudhoe Bay, Alaska Shipment Includes: Process Depth Start 9050/9080 Process Depth End 9510 / 9520 Process Date Start 05/02/98 Process Date End 05/06/98 Total Number of Samples Included in this Shipment 31 Shipment Number S-008-044 Comments 30' samples 9050i9080 thru 9260/9290. 10' samples 9290/9300 thru 9510/9520. 5631 Sílverado Way, Unit G, Anchorage AK 99518-1654 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company ) ) CONRmAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL CONFIDENTIAL 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging DTime Extension 0 Perforate o Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other IZI Change Approved Program 0 Operation Shutdown f.J Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' NSL, 4553' EWL, SEC. 19, T12N, R11E At top of productive interval 2233' NSL, 137' EWL, SEC. 20, T12N, R11E (Planned) At effective depth At total depth ~683' .NSL, 908' EWL, SEC. 20, T12N, R11 E (Planned) 12. Present well condition summary 5. Type of well: o Develo'pment [2J Exploratory o Stratigraphic D Service 6. Datum Elevation (OF or KB) KBE = 74.1 AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NWE 2-01 9. Permit Number 98-35/398-071 10. API Number 50-029-22866 11. Field and Pool Prudhoe Bay Field / Kuparuk River Oil Pool & Prudhoe Bay Pool Total depth: measured true vertical Effective depth: measured true vertical 7035 feet Plugs (measured) 6553 feet 7035 feet Junk (measured) 6553 feet MD TVD Casing Structural Conductor Surface Intermediate Production Liner 2626' Size Cemented 2664' 2664' 13-3/8" 1404 sx Coldset 11I,473 sx Class 'G' Length ORIGINAL Perforation depth: measured N/A true vertical NI A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Attachments ~ Description summary of proposal 14. Estimated date for commencing operation March 30, 1998 16. If proposal was verbally approved /}L/;J-/ f-{ (""<-ïV,) é ~].¿ Name of approver Contact Engineer Name/Number: Jim Smith, 564-5026 j h 'ì /(} ,y- 0'" Date approved J:""~E(¡"'E Ivr r"\ ¡,~ ,~ :Þ-ft,~ ~ ' """'." ~"". ,I~.," ~r f. ~J '~,"j 19Q!I .\¡ I; ~ i,I"'~, ¡ \. ~.....,. ¿ ~ 'Y' 0 ÄJaska Oil & Gas Cons. Gon;mlSSlon Anchorage o Detailed operations program o BOP sketch 15. Status of well classifications as: DOil DGas o Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. ~here~y certifYr1hat thef~e2g is tru~and correct to the best of my knowledge Igne Jim Smit¥J{7..,,,^p.:j '--',/ -.:--" ..::' Title Engineering Supervisor , Commission Use Only Conditions of Approval: Notify Commission so representative may witness .Approved CO~ug integrity __ BOP Test ~ Location clearance Jeìrned Mechanical Integrity Test _ Subs~quent form required 10-_~ <97 1 ~ '73 ûn~maJ SIgned By DavId W. Johnston Approved by order of the Commission Commissioner Form 1 0~403 Rev. 06/15/88 Date "%' ~ / c¡ ~ ! . ¡APproval NO.~-00<f Date Øf J Submit In Triplicate ') ) ARCO Alaska, Inc. BP EXPLORATION To: State of Alaska Date: March 27, 1998 From: Jim Smith SSD Senior Drilling Engineer Subject: NWE 2-01 Drilling Summary Amendment Shared Services Drilling submits this revision to the NWE 2-01 Drilling Permit Number 98-35 (API Number 50-029-22866). The primary change to programming is to the density and volume of intermediate cement necessary because shallow hydrocarbons have been identified in the intermediate hole below the surface casing shoe. To comply with policy, we propose to extend the top of cement to cover this hydrocarbon zone, since the resulting cement column will be very large a change in cement slurry density from 15.8 ppg to 13.1 ppg is desired. I n addition, geology has indicated that due to the correlation of formation tops it is likely the actual 9-5/8" casing seat will be about 25' above the Sag River. We plan to drill out of 9-5/8" with a rock bit and if a minimum of 20' of new hole is drilled below the 9-5/8" casing shoe a Leak off test will be obtained. If geology correlates that it is not possible to drill the full 20' prior to reaching core point, we plan to proceed with the program that was approved by your office (approval #398-071 of 3/23/98) to obtain the leak off test directly after the first 60' core below the casing shoe. PROGRAM TO BE AMENDED TO READ AS FOLLOWS: 14. Run and cement 9-5/8" 47# NSCC casing at the base of the Kingak (9300'md, 8631 'tvdss), cement using two stages as per the recommended practices with Class uG" cement in both stages. The first stage of 15.8 ppg cement will bring cement to 1000' above the Sag interval; the second stage of 13.1 ppg cement will cover from 100' below the Kuparuk interval to the surface casing shoe at 2664'MD. Bump the plug, confirm that the ES cementer is closed. 15. RIH with 8-1/2" bit, Drill out float equipment. Test 9-5/8" casing to 3000 psi for 30 minutes. Drill out shoe and formation to core point (Would like to core -10' of Kingak - therefore anticipate drilling only 2-3 ' of formation beneath shoe, however, if the rigsite geologist elects to drill a minimum of 20' of new hole, perform the required leak-off test per SSD Leak off Procedures prior to POOH for core barrel). Displace mud to the 9.6 ppg coring KCI mud system and ensure that it is within the specs of the well program. POOH. 16. Core 8-1/2" hole (4" core) to obtain -60 feet of the Sag river sands. ) ) 17. Perform a formation leak-off test as per the SSO Leak off Test Procedure at this time if the LOT was not obtained in step 15 above. 18. Drill 8-1/2" tangent to the Ivishak core point (rotary). 19. Core 8-1/2" hole (4" core) to obtain ",120 feet of Ivishak sands. 20. o rill 8-1/2" hole to TO of 10154'md or far enough below the base of the Ivishak interval to provide sufficient rat hole to run logs as well as sufficient rat hole so that the 7" landing collar is below any pay zones in order to eliminate a clean out trip. 21. Run platform express logs on eline (GR/RES/Oen/NEU). 22. Run DIPOLE SONIC on eline. 23. Run Numar logs on eline. 24. Run RFTs on eline. 25. Run and cement 7" 26# L-80 liner (150' of lap inside 9-5/8" casing). Test Casing. 26. Run and set a production packer with 3-1/2" L-80 tubing tail at the top Sag River (used to isolate Sag and Ivishak during well testing after rig departure). 27. Run 3-1/2" L-80 tubing completion with 3 GLMs and a 3-1/2" x 9-5/8" production packer set in the 9- 5/8" casing so that the tubing tail is ....100' above the Kuparuk productive horizon. 28. Test tubing and annulus. Set TWC. 29. NO BOP, NU and test tree. 30. Pull TWC, freeze protect, set BPV, ROMO. 31. Well will be tested by PE group following rig release. ) ) Well Plan Summary Type of Well (producer or injector): I Appraisal Producer I Surface Location: 453' FSL, 4553' FWL, T12N, R11 E, S19 X = 570682.31 , Y = 5986606.05 ** As Built 2233' FSL, 137' FWL,T12N,R11E,S20 X = 571080 Y = 5988390 2597' FSL, 761' FWL,T12N,R11E,S20 X = 571700 Y = 5988760 2683' FSL,908' FWL,T12, R11,S20 X = 571846 Y = 5988847 Primary Kuparuk Target Location: Primary Ivishak Target Location: Bottom Hole Location: I AFE Number: 4P1038 I Estimated Start Date: MD: 10154' I Rig: I Pool Rig 8 I 3/1/98 I Operating days to complete: 132 TVD: 9450'ss KBEI KBE = 74.1 Top of ice AMSL / Elevation (a.m.s.l) 43.0' I Well Design (conventional, slim hole, etc.): I Conventional Big Bore Build-Hold-Drop Profile Evaluate Reservoir Quality and Hydrocarbon presence in the Kuparuk, Sag, and Ivishak reservoirs, obtain -60' of 4" core in the Kuparuk C sand, obtain -60' of 4" core in the Sag river, obtain -120' of 4" core in the Ivishak sands Objective: ':"'< !r'~ ,..... Eft \' r ;.,:,-' {- (; - ~ ',~. ~.~ L" '\.., .., ci . t - 0\ '!~~('¡ "\ ¡ . fj,...~ r', t_.J . ~ '... v' ~.. ÞJasI<a OjJ {:: Ca3 Cons. CmT.mission )\nchorage ) Formation Markers Formation Tops Base Permafrost MD 1745 TVD (88) 1673 T-3 2273 2664 2201 2592 K-15 (Ugnu) 2713 2641 2832 2760 K-13 (West Sak / 4160 4015 Schrader) K-12 4434 4240 K-10 5076 4765 K-5 5749 5315 5945 5475 K-2 6485 5945 Kuparuk D 6970 6400 Kuparuk C 7038 6465 Kuparuk B (LCU) 7174 6595 Kuparuk A 7344 6758 Miluveach 7451 6860 Top Kingak 8089 7472 9300 8631 Sag River 9313 8644 Shublik 9359 8688 Top Sad 9558 8879 27P 9776 9088 26N 9870 9178 TO 10154 9450 ') Ultra-8limhole Design AS DRILLED AS DRILLED Surface casing point, 13-3/8" 68# L-80 Surface casing below the hydrate zone AS DRILLED AS PREDICTED FROM OFFSET Begin 2.5 per 100 build to 35 Deg Inc. Hard Stringer in NWE 1-01 Begin 2.5 per 100 Drop and Turn to target Cap rock for the Kuparuk reservoir Primary Target #1- Will core this interval (-60' of 4" core in the C1 and B sands) 9-5/8" 47# L-80 casing point above the Sag River Will core this interval (-60' of 4" core) Primary Target #2 - Will core this interval (-120' of 4" core) Casing point, 7" 26# L-80 ÇasingfTubing Program: Big Bore Design Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg 0.0. MDfTVD M DfTVDss 30" 20" 91.5# H40 WELD 80' surface 80'/80' 16" 13-3/8" 68# L-80 BTC 2664' surface 2664' /2592' 12-1/4" 9-5/8" 47# L-80 NSCC 9300' surface 9300'/8631 ' 8-1/2" 7" 26# L-80 BTCrnod 991' 9150'/8499' 10154' /9450' Tubing 3-1/2" 9.3# L-80 8RD EUE 6870' surface 6870'/6303' ) ) Mud Program: Big Bore Design HYDRATES!!!!! Based on offset well review, Hydrates are expected and must be managed safely. Surface Mud Properties: Fresh water bentonite spud mud Density (PPG) 8.6 at spud to 10.2 when reaching 1600' tvdss to section TD It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will most likely be encountered while drilling NWE 2-01. Offset well NWE 1-01 was drilled successfully while managing hydrates. 16" hole section Marsh Viscosity 150 Yield Point 20 10 sec gel 8 10 min pH API gel Filtrate 10 9 8-15 30 10 8-15 <100 60 15 Intermediate Mud Properties: 6% KCL Fluid 12-1/4" hole section Density Viscosity Yield 1 0 sec 10 min API HTHP (PPG) Point gel gel Fi It rate Filtrate Initial KCL 9.3+ at drill- 35-40 6-8 3-6 7-10 6-12 NA out of 13- 3/8" shoe, 2700'tvdss Final KCL ",,9.7 40-45 10-20 6-10 15-20 6-8 1 0-1 2 with drilled solids to the base HRZ/Kalubik (-·--6500'md) Kuparuk Mud Properties: Treated KCI mud system 12-1/4" hole section for the Kuparuk C core, will be conditioned at the base of the H RZ and then used to core the Kuparuk and drill to Base Kingak Density Viscosity Yield 10 sec 10 min pH API HTHP (PPG) Point gel gel Filtrate Filtrate Initial 10.2 at base of 45-55 1 5-25 6-8 8-12 8-9 4-6 1 0-12 KCI HRZ when treating coring fluid to specification (6500'md)d ) Final KCI 10.2-10.5 as needed to control Miluveach and Kingak shales 45-55 15-25 Production Mud Properties: Bland, Non-Invasive KCL coring Fluid will be used in coring the Sag and Ivishak. Formulation Water Bentonite Biocide (Aldacide G) Drispac SL Dextrid N-Vis KCI Calcium Carbo (5 micron) Deuterium Oxide Tracer Barite Viscosity Yield Point 12-18 Density (PPG) 9.6 at drill out of 9-5/8" shoe (8644'tvdss) to TO Directional KOP: Maximum Hole Angle: Close Approach Well: 45-55 Cement: Big Bore Design Casing/Liner 13-3/8" surface Lead Sx / Wt / Yield Cold Set III Lead: 1550/12.2/1.92 10 see gel 4-8 10 min gel 8-12 ) 6-8 8-12 8-9 4-6 10-12 8-1/2" hole section 0.916 bbl 7 ppb 0.5 ppb 1.75 ppb 8 ppb 0.25-0.5 ppb 20.7 ppb 57.4 ppb 0.03 gal/bblliquid phase(added) as needed pH API Filtrate <4.0 HTHP Filtrate <7.5 7.5-8.5 ±2832' MO (estimated), below surface casing shoe ±35.2° None Tail Sx I Wt / Yield Class "G" tail: 473/15.8/1.15 Comments Davis Lynch Screw in Cement Job: Lead calculated as Cold Set III from 2022'md to surface @250%. Tail calculated as Class "G" cement circulated from section TO to 750'md above the shoe @50% excess "') ) Casing/Liner 9-5/8 " Intermediate First Stage Sx 1 Wt 1 Yield Class "G" Tail: 439/15.8/1 .15 Second Stage Sx 1 Wt 1 Yield Class "G" Tail: 1 015/13.1/1.96 Comments Two Stage Job: First stage calculated as 1 OOO'md Class "G" tail above casing shoe/Sag River with 50% excess Second stage calculated as Class "G" cement fill from 1 00' below the Kup A to surface casing shoe at 2664' with 30% excess. 7" Lead Sx / Wt / Yield 232/15.8/1.15 Solid cemented liner, Class "G", TOC 200' above liner top with 50% open hole excess Production Logging Program LWD Logging: 16" Hole MWD directionallGR/RES, Mug Logging 12-1/4" Hole MWD directional/GR/RES, Mud Logging 8-1/2" Hole MWD directional/GR/RES, mud Logging Open Hole Logs (eline): 16" Hole NONE 12-1/4" Hole 1) Platform Express (GR/RES/Den/NUE) 2) Dipole Sonic 3) CMR 4) FMI From Base Kuparuk to 5) Optional Percussion SWC and RFTs if hydrocarbons are encountered surface casing in West Sak 8-1/2" Hole 1) Platform Express (GR/RES/DEN/NUE) 2) Dipole Sonic 3) Numar 4) RFTs Cased Hole Logs (eline): 1) USIT/GR 2) CNL t~E(~El'fr'h ~~~~ ~'V r,'.; t....::__ '.:-.....~.¡, -. 7 . <"i " r, 9 q Q - "I.... ,:ll:ls"a (~a " ." d..!\ J:¡ :~i Gas Con' C ,...,~.' " "', , h S. O¡;¡l1/SSlon l-<r1C, orage ) ') "c CONFIDENTiAl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL CONFIDENTIAL 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging 0 Time Extension 0 Perforate o Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other [XJ Change Approved Program 0 Operation Shutdown [J Re-Enter Suspended Well 0 Stimulate --....---.".-,.. -...---. 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' NSL, 4553' EWL, SEC. 19, T12N, R11 E At top of productive interval 2233' NSL, 137' EWL, SEC. 20, T12N, R11 E (Planned) At effective depth 5. Type of well: o Development ~ Exploratory o Stratigraphic o Service 6. Datum Elevation (OF or KB) KBE = 74.1 AMSL 7. Unit or Property Name Prudhoe Bay Unit At total depth 2683' NSL, 908' EWL, SEC. 20, T12N, R11 E (Planned) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8. Well Number NWE 2-01 9. Permit Number 98-35 10. API Number 50-029-22866 11. Field and Pool Prudhoe Bay Field I Kuparuk River Oil Pool & Prudhoe Bay Pool Casing Structural Conductor Surface I ntermed ¡ate Production Liner 2680 feet Plugs (measured) 2680 feet 2680 feet Junk (measured) 2680 feet Length Size Cemented MD TVD 2626' 13-3/8" 1404 sx Coldset III, 473 sx Class 'G' 2664' 2664' ORIGINAL Perforation depth: measured N/A true vertical N/ A r" \~ It' ,\ I', Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Attachments :g] Description summary of proposal 14. Estimated date for commencing operation March 24, 1998 16. If proposal was verbally approved o Detailed operations program o BOP sketch 15. Status of well classifications as: DOil DGas o Suspended Name of approver ~ Date approved Contact Engineer Name/Number: Greg est, 5f14- 8 3 Prepared By Name/Number: 17. I ~ereby certify that the ~ goinc i }Jüe and correct to the best Of~Y k~owledge Signed 1:) À ,\~h,~. Tim A. Burns 1\, Il~ Title Engineering Supervisor .... Commission Use Only Conditions of ApgrQ)CåP:'1 Notify Commission so representative may witn~ss ~o",e Plug integrity ___ BOP Test ~ Location clearance J r ~99~e \ echanicallntegrity Test ____ Subsequent form r_equired 1 O-~~~_ 'd:. urlginal Signed ~y David W. Johnston Service Terrie Hubble, 564-4628 Date ¥ I fie¡ y I Approval NOJ7 ~--6)1 Commissioner Date~d3 q~ ~ sUb';;lt In Tri~licate .u Approve by 0 der of the Commission Form 10-403 Rev. 06/15/88 -) ) ARCO Alaska, Inc. BP EXPLORATION To: State of Alaska Date: March 16, 1998 From: G reg West Pool 8 Operations Drilling Engineer Subject: NWE 2-01 Drilling Summary Amendment Shared Services Drilling submits this revision to the NWE 2-01 Drilling Permit Number 98-35 (API Number 50-029-22866). The primary change to programming is that SSD will drill out the 9-5/8" shoe, core -60' of Sag, and then perform a LOT. The original permit to drill listed operations as drilling out the 9-5/8" shoe and new formation, performing a LOT, then coring the Sag. ORIGINAL PERMIT SUMMARY STARTING AT RUNNING 9-5/8" CASING: 14. Run and cement 9-5/8" 47# L-80 casing to surface and cement using two stages as per the recommended practices with Class "G" cement in both stages. The first stage will bring cement to 1 000' above the Sag interval; the second stage will cover from 50' below the Kuparuk interval to 1000' above the Kuparuk interval. Bump the plug, confirm that the ES cementer is closed. 15. RIH with bit, Drill out float equipment and all casing internal jewelry to a few feet within the casing shoe. Test 9-518" casing to 3000 psi for 30 minutes. Clean up the coring KCI mud system to ensure that it is within the specs of the well program. Drill out shoe and 10' of new formation; perform a formation leak-off test as per the SSD Leak off Test Procedure. 16. Drill 8-1/2" hole to core point. 17. Core 8-1/2" hole (4" core) to obtain -60 feet of the Sag river sands. 18. Drill 8-1/2" tangent to the Ivishak core point. 19. Core 8-1/2" hole (4" core) to obtain -120 feet of Ivishak sands. 20. Drill 8-1/2" hole to TD of 10154'md or far enough below the base of the Ivishak interval to provide sufficient rat hole to run logs. 21. Run platform express logs on eline (GR/RES/Den/NEU). 22. Run DIPOLE SONIC on eline. 23. Run Numar logs on eline. 24. Run RFTs on eline. 25. Run and cement 7" 26# L-80 liner (150' of lap inside 9-5/8" casing). Test Casing. 26. Run and set a production packer with 3-1/2" L-80 tubing tail at the top Sag River (used to isolate Sag and Ivishak during well testing after rig departure). ) ') 27. Run 3-1/2" L-80 tubing completion with 3 GLMs and a 3-1/2" x 9-5/8" production packer set in the 9- 5/8" casing so that the tubing tail is -100' above the Kuparuk productive horizon. 28. Test tubing and annulus. Set TWC. 29. NO BOP, NU and testtree. 30. Pull TWC, freeze protect, set BPV, ROMO. 31. Well will be tested by PE group following rig release. TO BE AMENDDED TO READ AS FOLLOWS: 14. Run and cement 9-5/8" 47# NSCC casing at the base of the Kingak (9300'md, 8631 'tvdss), cement using two stages as per the recommended practices with Class "G" cement in both stages. The first stage will bring cement to 1 000' above the Sag interval; the second stage will cover from 1 00' below the Kuparuk interval to 1000' above the Kuparuk interval. Bump the plug, confirm that the ES cementer is closed. 15. RIH with 8-1/2" bit, Drill out float equipment. Test 9-5/8" casing to 3000 psi for 30 minutes. Drill out shoe and formation to core point (Would like to core -10' of Kingak - therefore anticipate drilling only 2-3 ' of formation beneath shoe). Displace mud to the 9.6 ppg coring KCI mud system and ensure that it is within the specs of the well program. POOH. 16. Core 8-1/2" hole (4" core) to obtain ,..,60 feet of the Sag river sands. 17. RIH with 8-1/2" bit, perform a formation leak-off test as per the SSD Leak off Test Procedure. 18. Drill 8-1/2" tangent to the Ivishak core point (rotary). 19. Core 8-1/2" hole (4" core) to obtain ,..,120 feet of Ivishak sands. 20. Drill 8-1/2" hole to TO of 1 0154'md or far enough below the base of the Ivishak interval to provide sufficient rat hole to run logs as well as sufficient rat hole so that the 7" landing collar is below any pay zones in order to eliminate a clean out trip. 21. Run platform express logs on eline (GR/RES/Den/NEU). 22. Run DIPOLE SONIC on eline. 23. Run Numar logs on eline. 24. Run RFTs on eline. 25. Run and cement 7" 26# L-80 liner (150' of lap inside 9-5/8" casing). Test Casing. 26. Run and set a production packer with 3-1/2" L-80 tubing tail at the top Sag River (used to isolate Sag and Ivishak during well testing after rig departure). 27. Run 3-1/2" L-80 tubing completion with 3 GLMs and a 3-1/2" x 9-5/8" production packer set in the 9- 5/8" casing so that the tubing tail is ,..,100' above the Kuparuk productive horizon. 28. Test tubing and annulus. Set TWC. 29. NO BOP, NU and test tree. 30. Pull TWC, freeze protect, set BPV, RDMO. 31. Well will be tested by PE group following rig release. ') ') Well Plan Summary Type of Well (producer or injector): I Appraisal Producer I Surface Location: 453' FSL, 4553' FWL, T12N, R11E, S19 X = 570682.31 , Y = 5986606.05 ** As Built 2233' FSL, 137' FWL,T12N,R11E,S20 X = 571080 Y = 5988390 2597'FSL, 761'FWL,T12N, R11E,S20 X = 571700 Y = 5988760 2683' FSL, 908' FWL, T12, R11,S20 X = 571846 Y = 5988847 Primary Kuparuk Target Location: Primary Ivishak Target Location: Bottom Hole Location: I AFE Number: 4P1038 I Estimated Start Date: MD: 10154' I Rig: I Pool Rig 8 I 3/1/98 I Operating days to complete: 132 TVD: KBEI KBE = 74.1 Top of ice AMSL I =:Ievation (a.m.s.l) 43.0' 9450'ss I Well Design (conventional, slim hole, etc.): Conventional Big Bore Build-Hold-Drop Profile Evaluate Reservoir Quality and Hydrocarbon presence in the Kuparuk, Sag, and Ivishak reservoirs, obtain ,..,60' of 4" core in the Kuparuk C sand, obtain ,..,60' of 4" core in the Sag river, obtain,.., 120' of 4" core in the Ivishak sands Objective: ) Formation Markers Formation Tops MD TVD (SS) Base Permafrost 1745 1673 T-3 2273 2201 2664 2592 K-15 (Ugnu) 2713 2641 2832 2760 K-13 (West Sak / 4160 4015 Schrader) K-12 4434 4240 K-10 5076 4765 K-5 5749 5315 5945 5475 K-2 6485 5945 Kuparuk D 6970 6400 Kuparuk C 7038 6465 Kuparuk B (LCU) 7174 6595 Kuparuk A 7344 6758 Miluveach 7451 6860 Top Kingak 8089 7472 9300 8631 Sag River 9313 8644 Shublik 9359 8688 Top Sad 9558 8879 27P 9776 9088 26N 9870 9178 TO 10154 9450 ) Ultra-Slimhole Design AS DRILLED AS DRILLED Surface casing point, 13-3/8" 68# L-80 Surface casing below the hydrate zone AS DRILLED AS PREDICTED FROM OFFSET Begin 2.5 per 100 build to 35 Deg Inc. Hard Stringer in NWE 1-01 Begin 2.5 per 100 Drop and Turn to target Cap rock for the Kuparuk reservoir Primary Target #1- Will core this interval (-60' of 4" core in the C1 and B sands) 9-5/8" 47# L-80 casing point above the Sag River Will core this interval (-60' of 4" core) Primary Target #2 - Will core this interval (-120' of 4" core) Casing point, 7" 26# L-80 Casingrrubing Program: Big Bore Design Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg 0.0. MDrrVD M DrrVDss 30" 20" 91.5# H40 WELD 80' surface 801/80' 16" 13-3/8" 68# L-80 BTC 2664' surface 2664' /2592' 12-1/4" 9-5/8" 47# L-80 NSCC 9300' surface 9300'/8631 ' 8-1/2" 7" 26# L-80 BTCmod 991' 9150'/8499' 1 0154' /9450' Tubing 3-1/2" 9.3# L-80 8RD EUE 6870' surface 6870'/6303' ) ) Mud Program: Big Bore Design HYDRATES!!!!! Based on offset well review, Hydrates are expected and must be managed safely. Surface Mud Properties: Fresh water bentonite spud mud Density (PPG) 8.6 at spud to 10.2 when reaching 1600' tvdss to section TO It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will most likely be encountered while drilling NWE 2-01. Offset well NWE 1-01 was drilled successfully while managing hydrates. 16" hole section Marsh Viscosity 150 Yield Point 20 10 sec gel 8 10 min pH API gel Filtrate 10 9 8-15 30 10 8-15 <100 60 15 Intermediate Mud Properties: 6% KCL Fluid 12-1/4" hole section Density Viscosity Yield 1 0 sec 10 min API HTHP (PPG) Point gel gel Filtrate Filtrate Initial KCL 9.3+ at drill- 35-40 6-8 3-6 7-10 6-12 NA out of 13- 3/8" shoe, 2700'tvdss Final KCL -9.7 40-45 1 0-20 6-10 15-20 6-8 1 0-12 with drilled solids to the base HRZ/Kalubik (-6500'md) Kuparuk Mud Properties: Treated KCI mud system 12-1/4" hole section for the Kuparuk C core, will be conditioned at the base of the HRZ and then used to core the Kuparuk and drill to Base Kingak Density Viscosity Yield 10 sec 10 min pH API HTHP (PPG) Point gel gel Filtrate Filtrate Initial 10.2 at base of 45-55 15-25 6-8 8-12 8-9 4-6 1 0-12 KCI HRZ when treating coring fluid to specification (6500'md)d .. t ~ ) Final KCI 10.2-10.5 as needed to control Miluveach and Kingak shales 45-55 15-25 Production Mud Properties: Bland, Non-Invasive KCL coring Fluid will be used in coring the Sag and Ivishak. Formulation Water Bentonite Biocide (Aldacide G) Drispac SL Dextrid N-Vis KCI Calcium Carbo (5 micron) Deuterium Oxide Tracer Barite Viscosity Yield Point 12-18 Density (PPG) 9.6 at drill out of 9-5/8" shoe (8644'tvdss) to TO Di rectional KOP: Maximum Hole Angle: Close Approach Well: 45-55 Cement: Big Bore Design Casing/Liner 13-3/8" surface Lead Sx / Wt / Yield Cold Set III Lead: 1550/12.2/1.92 10 sec gel 4-8 10min gel 8-12 ') 6-8 4-6 1 0-12 8-12 8-9 8-1/2" hole section 0.916 bbl 7 ppb 0.5 ppb 1.75 ppb 8 ppb 0.25-0.5 ppb 20.7 ppb 57.4 ppb 0.03 gal/bblliquid phase(added) as needed pH API Fi Itrate <4.0 HTHP Filtrate <7.5 7.5-8.5 ±2832' MD (estimated), below surface casing shoe ±35.2° None Tail Sx / Wt / Yield Class "G" tail: 473/15.8/1.15 Comments Davis Lynch Screw in Cement Job: Lead calculated as Cold Set III from 2022'md to surface @250%. Tail calculated as Class "G" cement circulated from section TD to 750'md above the shoe @50% excess ) ') Casing/Liner 9-518" Intermediate First Stage Sx 1 Wt 1 Yield Class "G" Tail: 439/15.8/1.15 Second Stage Sx 1 Wt 1 Yield Class "G" Tail: 613/15.8/1.15 Comments Two Stage Job: First stage calculated as 1 OOO'md Class "G" tail above casing shoe/Sag River with 50% excess Second stage calculated as Class "G" cement fill frOm 1 00' below the Kup A to 1000' md above the top Kuparuk D with 50% excess. 7" Lead Sx 1 Wt 1 Yield 232/15.8/1.15 Solid cemented liner, Class "G", TOC 200' above liner top with 50% open hole excess Production Logging Program LWD Logging: 16" Hole MWD directional/GR/RES, Mug Logging 12-1/4" Hole MWD directional/GR/RES, Mud Logging 8-1/2" Hole MWD directional/GR/RES, mud Logging Open Hole Logs (eline): 16" Hole NONE 12-114" Hole 1) Platform Express (GR/RES/Den/NUE) 2) Dipole Sonic 3) CMR 4) FMI From Base Kuparuk to 5) Optional Percussion SWC and RFTs if hydrocarbons are encountered surface casing in West Sak 8-1/2" Hole 1) Platform Express (GR/RES/DEN/NUE) 2) Dipole Sonic 3) Numar 4) RFTs Cased Hole Logs (eline): 1) USIT/GR 2) CNL 'I 1.''- "i: \1....... .. ~ -,- '. '~ ' . "'1:'"" ) ) MEMORANDUM TO: David JOhnst/ Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 17, 1998 THRU: Blair Wo~dzell, 4{Q,..(., .sf?1 P. I. Supervisor FROM: John spaUldin~ Petroleum Insp. FILE NO: a99leoee.doc SUBJECT: BOPE Test Pool 8 N.W. Eileen 2-01 Expl. BPX Prudhoe Bay PTD 98-35 Tuesday March 17. 1998: I traveled to BPX's Wildcat well N. W. Eileen to witness the BOPE test on Pool rig 8. The attached AOGCC BOPE Test Report form is attached for reference. As noted on the test form no failures were observed. The crew appears to be quite inexperienced'J Testing went quite slow in order for the new hands to be able to grasp what was going on hence the longer test time. I believe given time ,.. ~. and patience this crew will do ok. :7-': ,i.". ~ r: ,,;1. c.. ~ / "J\.~ /' ~ -ý Summary: I witnessed the BOPE Test, Pool rig 8 31 valves, 0 failures, 8 hours Attachments: a99leoee.xls Unclassified Confidential (Unclassified if document removed) X Confidential . ) \ ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Arctic Alaska Operator: BPX Well Name: NEW 2-01 Casi ng Size: 9 5/8" Set @ Test: Initia X Weekly DATE: 3flY98 Rig No. 8 PTD # 98-35 Rig Ph.# Rep.: L.C. Gentry Rig Rep.: David Lancaster Location: Sec. 19 T. 12N R. 11E Meridian UM Other ,'</TESJF::[)ATA " Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: ok Well Sign ok Upper Kelly I I BOP 1 500/5,000 P Housekeeping: ok (Gen) Dr!. Rig ok Lower Kelly I I BOP 1 500/5,000 P PTD On Location Ok Hazard Sec. ok Ball Type 1 500/5,000 P Standing Order Pos~ ok Inside BOP 1 500/5,000 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 300/3,000 P CHOKE MANIFOLD: Pressure P/F Pi pe Rams 1 500/5,000 P No. Valves 19 500/5,000 P ~ower Pi pe Rams 1 500/5,000 P No. Flanges 45 500/5,000 P Blind Rams 1 500/5,000 P Manual Chokes 2 Functioned P Choke Ln. Valves 1 500/5,000 P Hydraulic Chokes 1 Functioned P HCR Valves 2 500/5,000 P Kill Line Valves 1 500/5,000 P ACCUMULATOR SYSTEM: Check Valve NA System Pressure 3,000 P Pressure After Clo~"Jre ' 1,400 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 24 sec. Trip Tank ok ok System Pressure Attained 3 minutes 2ïi sec. Pit Level Indicators ok ok Blind Switch Covers: Master: X Remote: X Flow Indicator ok ok Nitgn. Btl's: 5 @ 2100 avg. Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok /L"IJ"12S1\R.ESULJ'tS; Number of Failures: 0 ,Test Time: 8.0 Hours. Number of valves tested 31 Repair or Replacement of Failed Equipment will be made within 0 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Rig was in very good shape, the crew was quite inexperienced hence the longer test time. Distribution: orig-Well File c - Oper.lRig c - Database c - Trip Rpt File c - Inspector FI-021 L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO Waived By: Witnessed By: John H. SpDulding 24 HOUR NOTICE GIVEN YES X NO A99leoee.xls l / MEMORANDUM /// TO: David JOh~ Chairman THRU: Blair Wondzell <: h ""... /1 , P. I. Supervisor 3 - J.:. Lou Grimaldi, :..J 6- Petroleum Inspector FROM: ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 9, 1998 FILE NO: EW9JCIFE.DOC SUBJECT: Diverter inspection Pool rig #8 ~, ,X~~I'~"~~5W",..E 2,-01 P ,,',. 0",.", , ...J Mondav, March ~, 1998: I traveled to the BPX exploratory well #NWE 2-01 to witness the Diverter function test on Pool rig #8 which was preparing to drill surface hole. The Diverter assembly was assembled when I arrived. I made a in depth inspection of the rig, which was in good shape. The 16-inch knife valve used on the vent line operated quickly and was open well before the annular closed. The 21 %" annular preventer had a closure time of 20 seconds. The accumulator had a recharge time of 1 minute 45 seconds and appeared to be in good shape. The gas detection system was calibrated and tested. I walked the vent line and found a good solid construction. The line terminated 90 feet from the sub-base of the rig and although they seemed sturdy I requested the wire spools used for support be replaced with some solid wood dunnage. This rig is operating for the first time on the North Slope. It appeared to have been well modified and is a fine looking rig. SUMMARY: I witnessed the Diverter function test on Pool rig #8. Better support for the vent line was required. Attachments: EW9JCIFE.XLS cc: Steve Walls/John Raul (Shared Services Drilting) NON-CONFIDENTIAL ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Drlg Contractor: Pool Operator: BP Exploration Well Name: NEW 2~01 Location: Sec. 19 1. 12N MISC. INSPECTIONS: Location Gen.: P Housekeeping: P Reserve Pit: NIA Well Sign: (Gen.) Drtg. Rig: Flare Pit: P P N/A DIVERTER SYSTEM INSPECTION: Diverter Size: 21 1/4 in. Divert Valve(s) Full Opening: P Valve(s) Auto & Simuttaneous: P , Vent Line(s) Size: 16 in. Vent Line(s) Length: 110ft. Line(s) Bifurcated: NIA Line(s) Down Wind: P Line(s) Anchored: F Turns Targeted / Long Radius: N/A R. Operation: Rig No. Oper. Rep.: Rig Rep.: 11E Date: 3/9/98 Development Exploratory: X 8 PTD # 98-0035 Rig Ph. # Red Gentry/Charlie Dickson Darrell Greene! Gary Goorich Merdian Umiat "TEST DATA" ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: 1 Nitrogen Bottles: Six Bottles 2100 avera9ed 3000 psig 1850 psig min. 20 sec. min. 45 sec. psig MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: Light Alarm P P P P P P Light Alarm p p P P GAS DETECTORS: Methane Hydrogen Sutfide: "D~RTE~ SCHE_MATIC ( +-t North ~ '1wind I '" '\ II Camp II L-L -Ð -~+ ./ Non Compliance Items 1 Repair Within Now Day (s) And contact the Inspector @ 659~3607 Remarks: Replace supports under vent line with more substantial Dunnage. Good looking rig. Distribution orig. - Well File c - OperlRep c - Database c - Trip Rpt File c - Inspector DVTRINSP.xL T (REV. 1128/97) L.G. AOGCC REP.: Lou Grimaldi OPERATOR REP.: Darrell Greene Ew9jcife Report prepared 3/19/98 --. ') ,:) TONY KNOWLES, GOVERNOR ALASKA OIL Al\ID GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 23~ 1998 James Smith Engineering Supervisor BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit NWE 2-01 BP Exploration (Alaska) Inc. Permit No. 98-35 Sur. Loc. 453~SL~ 4553'EWL. Sec. 19, TI2N. RIlE. UM Btmhole Loc. 2683'NSL. 908'E\VL. Sec. 20. TI2N. Rll E. UM Dear Mr. Smith: Encloscd is the approved application for permit to drill the abovc referenced well. The permit to drill docs 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 arc made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's intcrnal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum tìcld inspector on the North Slope pa . r a~ 659-3 David W. J<;>hnston -- Chainnan . "---- BY ORDER OF THE COMl\'lISSION ~- ~~ dlf/Enclosures cc: Department of Fish & Game_ Habitat Section \\'/0 encl. Department of Environmental Conservation \\'/0 encl. CONF:DENTIAI. , ) STATE OF ALASKA·" ), ALl'" JKA u'IL AND GAS CONSERVATIG.. 4 vOMMISSION PERMIT TO DRILL 20 AAC 25.005 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner 1 a. Type of work ~ Drill D Redrill 1 b. Type of well D Re-Entry D Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' NSL, 4553' EWL, SEC. 19, T12N, R11E At top of productive interval 2233' NSL, 137' EWL, SEC. 20, T12N, R11 E At total depth 2683' NSL,908' EWL, SEC. 20,T12N, R11E 12. Distance to nearest property linel13. Distance to nearest well ADL 047449,2683' No Close Approach 16. To be completed for deviated wells Kick Off Depth 2832' MD Maximum Hole AnQle 18. Casing Program Size, . Hole Casing 30" 20" 16" 13-3/8" 12-1/4" 9-5/8" 8-1/2" 7" Specifications Weight 91.5# 68# 47# 26# Grade H-40 L-80 L-80 L-80 Length 80' 2772' 9313' 991' Coupling Weld BTC NSCC BTC-Mod Perforation depth: measured CONFIDENTIAL ~ Exploratory D Stratigraphic Test D Development Oil D Service D Development Gas D Single Zone . D Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RTE = 43' 6. Property Designation ADL 047446 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NWE 2-01 9. Approximate spud date 02/26/98 14. Number of acres in property' 15. Proposed depth (MD and TVD) 2560 10154' MD /9450' TVDss 17. Anticipated pressure {see 20 MC 25.035 (e) (2}} 35.2° Maximum surface 3512 psig, At total depth (TV D) 8879' /4004 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 80' 80' Surface Surface 2772' 2700' Surface Surface 9313' 8644' 9163' 8499' 10154' 9450' Prudhoe Bay Field / Kuparuk River Oil Pool & Prudhoe Bay Pool 11 . Type Bond (See 20 MC 25.025) Number 2S100302630-277 Amount $200,000.00 Quantity of Cement (include stage data) 260 sx Arctic Set (Approx.) 1550 sx Cold Set III, 473 sx IG' 1052 sx Class 'G' 232 sx Class 'G' MD TVD RECEIVED Cï="a ~I f1 lQQ8 \L :")~¡,",, ORIGfNAL true vertical Alaska 011 & Gas Cons, ComrnissÎon Ancho rage 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 MC 25.050 Requirements Contact Engineer Name/Number: Greg West, 564-4803 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify t t the fOregO¡ngpiS tr and correct to the best of my knowledge It f Signed L é) 'If OR- Title Engineering Supervisor Date (\) Commission Use Only Approval Date (?) ~--,d.2J - 90 Samples Required l8IYes D No Mud Log Required Hydrogen Sulfide Measures DYes;s::l No Directional Survey Required Required Working Pressure for BOPE D 2M; D 3M; jR.SM; D 10M; Other: Permit ~mber /~-3:~ Conditions of Approval: API Number 50- 02-<7'- ¿z.?,6 6' Approved By Form 1 0-401 Rev. 12-01-85 Original Sign:~tl ~ David W. ,Johnstn~ See cover letter for other requirements DYes 5aNo ~Yes DNo D15M Commissioner by order of the commission Date d .;):3 9~ Submit In Triplicate ) ) i Rell Name: .\ I NWE 2-0'1 ,/ )J I CONFIDENTIAL Well Plan Summary Type of Well (producer or injector): I Appraisal Producer I Surface Location: 453' FSL, 4553' FWL, T12N, R11E, S19 X = 570682.31 , Y = 5986606.05 ** As Built 2233' FSL, 137' FWL,T12N, R11E,S20 X = 571080 Y = 5988390 2597' FSL, 761' FWL,T12N, R11E,S20 X = 5711700 Y = 5988760 2683' FSL, 908' FWL,T12, R11,S20 X = 571846 Y = 5988847 Primary Kuparuk Target Location: Primary Ivishak Target Location: Bottom Hole Location: I AFE Number: 14P1038 I Rig: I Pool Rig 8 I Estimated Start Date: I 2/26/98 I Operating days to complete: 140 MD: 10154' TVD: 9450'ss RKB/ TBA/ Top of ice =Ievation 43.0' (a.m.s.l) I Well Design (conventional, slimhole, etc.): I Conventional Big Bore Build-Hold-Drop Profile Objective: Evaluate Reservoir Quality and Hydrocarbon presence in the Kuparuk, Sag, and Ivishak reservoirs, obtain ......60' of 4" core in the Kuparuk C sand, obtain .....60' of 4" core in the Sag river, obtain ......120' of 4" core in the Ivishak sands ,! r \1''''',\, ~. t" ~ '\ ,I ¡"", ~ ~ R E~' , ' :,' ~:; ~ ",j ~ ~ \,.., ~ 'I¡. ..... ~. ~ ..... ~", . '''i I; -\Q:...¡,)<,. .- ;.- \ ) ¡" ì " '- \" :;- ____u \ '.' ' ((ÙSS\Ü\ \ r. '~c; COn-b.· . , ... ('':\5 \..;o\·~, \J'I"\" 'Iv. p,\ê-SKci ' :.:' ÞJ':cnorage ) ) Formation Markers Formation Tops MD Base Permafrost 1772 TVD (SS) 1700 T-3 K-15 (Ugnu) 2187 2477 2772 2115 2405 2700 K-13 (West Sak / Schrader) K-12 K-10 K-5 K-2 Kuparuk D Kuparuk C 4160 4015 4434 5076 5749 6485 6970 7038 4240 4765 5315 5945 6400 6465 Kuparuk B (LCU) Kuparuk A Miluveach Top Kingak 7174 7344 7451 8089 9300 6595 6758 6860 7472 8631 Sag River Shublik Top Sad 9313 9359 9558 8644 8688 8879 27P 26N TD 9776 9870 10154 9088 9178 9450 ) ) ! CONFIDENTIAL Ultra-Slimhole Design Based on offset West Kup & NWE State #1 Surface casing point in shale, 13-318" 63# L-80 Surface casing below the hydrate zone Cap rock for the Kuparuk reservoir Primary Target #1- Will core this interval (-60' of 4" core) 9-5/8" 47# L-80 casing point above the Sag River Will core this interval (-60' of 4" core) Primary Target #2 - Will core this interval (-120' of 4" core) Casing point, 7" 26# L-80 CasinQfTubinQ PrOQram: BiQ Bore DesiQn Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDfTVD MDfTVDss 30" 20" 91.5# H40 WELD 80' surface 80'/80' 16" 13-3/8" 68# L-80 BTC 2772' surface 2772' /2700' 12-1/4" 9-5/8" 47# L-80 BTC 9313' surface 9313'/8644' 8-1/2" 7" 26# L-80 NSCC 991' 9163' /8499' 10154' /9450' Tubing 3-1 /2" 12.6# L-80 8RD EUE 6870' surface 6870'/6303' 2 ) )\ General Mud Proaram: Bia Bore Desian HYDRATES!!! !! ) / CONFIDENTIAL Based on offset well review, Hydrates are expected and must be managed safely. Surface Mud Properties: Fresh water bentonite spud mud Density (PPG) 8.6 at spud to 10.2 before reaching 1600' tvdss to section TD It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will most likely be encountered while drilling NWE 2-01. Offset well NWE 1-01 was drilled successfully while managing hydrates. 16" hole section Marsh Viscosity 150 Yield Point 15 10 sec gel 8 10min gel 10 pH 9 API Filtrate 8-15 <100 35 15 30 10 8-15 Intermediate Mud Properties: Fresh Water LSND 12-1/4" hole section Density Viscosity Yield 1 0 sec 10min API HTHP (PPG) Point gel gel Filtrate Fi It rate Initial LSND 9.3 at drill- 35-40 6-8 3-6 7-10 6-12 NA out Final LSND 9.6-10.2 40-45 10-20 6-10 15-20 4-6 1 0-12 with drilled soilds to the base HRZ (-6900'md) Kuparuk Mud Properties: Treated KGI mud system 12-1/4" hole section for the Kuparuk G core, will be displaced at the base of the HRZ Density Viscosity Yield 10 sec 10 min pH API HTHP (PPG) Point gel gel Filtrate Filtrate Initial 10.2 at 45-55 15-20 6-8 8-12 8-9 4-6 1 0-12 KGI displacement Final 10.2-10.5 45-55 15-20 6-8 8-12 8-9 4-6 1 0-12 KGI 3 ) ) Production Mud Properties: Bland, Non-Invasive coring Fluid will be used in coring tha Sag and Ivishak. This fluid will be used to drill out the intermediate casing shoe. Formulation Water Bentonite Biocide (Aldacide G) Drispac SL Starch XCD KCI Calcium Carbo (5 micron) Deuterium Oxide Tracer Barite ) ,I CONFIDENTIAL 8-1/2" hole section 0.87 bbl 7-8 ppb 0.5 ppb 1.75 ppb 7 -8 ppb 0.25 ppb 6°1o 60+ ppb 850 ppm (added) as needed Density (PPG) 9.6 at drill out Yield Point 20-30 10 sec gel 4-8 10 min pH gel 8-12 7.5-8.5 HTHP Filtrate <8.0 Viscosity ALAP Directional KOP: Maximum Hole Angle: Close Approach Well: API Fi It rate <4.0 ±2832' MD (estimated), below surface casing shoe ±35.2° None Cement: Bic Bore Design Lead Sx / Wt / Yield Cold Set III Lead: 1550/15.8/1.15 Tail Sx / Wt / Yield Class "G" tail: 473/12.2/1.92 Casing/Liner 13-3/8" surface Casing/Liner 9-5/8" Intermediate First Stage Sx / Wt / Yield Class "G" Tail: 439/15.8/1.15 Second Stage Sx / Wt / Yield Class "G" Tail: 613/15.8/1.15 7" Production Lead Sx / Wt / Yield 232/15.8/1.15 Comments Screw in Cement Job: Lead calculated as Cold Set III from 1900'md to surface @2500/0. Tail calculated as Class "G" cement circulated from section TD to 750'md above the shoe @500/0 excess Comments Two Stage Job: First stage calculated as 1000'md Class "G" tail above the Sag River assuming 50°/0 excess Second stage calculated as Class "G" cement fill form 50' below the Top Miluveach to 1000' md above the top Kuparuk assuming 50°/0 excess. Solid cemented liner, Class "G", TOC 200' above liner top assuming 50°/0 open hole excess I 4 ) ) Loqaina Proaram L WD Logging: ) CONFIDENTIAL 16" Hole MWD directional/GR, Mug Logging 12-1/4" Hole MWD directional/GR/RES, Mud Logging 8-1/2" Hole MWD directional/GR/RES, mud Logging Open Hole Logs (eline): 16" Hole 1) Platform Express (GR/RES/DEN/NUE) 2) Dipole Sonic 12-1/4" Hole 1) Platform Express (GR/RES/Den/NUE) 2) Dipole Sonic 3) CMR 4) FMS From Base Kuparuk to 5) Optional Percussion SWC and RFTs if hydrocarbons are encountered surface casing in West Sak 8-1/2" Hole 1) Platform Express (GR/RES/DEN/NUE) 2) Dipole Sonic 3) Numar 4) RFTs Cased Hole Logs (eline): 1) USIT/GR 2) CNL 5 ) ) ,'. ) / ), CONFIDENTIAL Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics for Pool 8 will be supplied to the AOGCC Maximum anticipated bottom hole pressure within the Kuparuk is -4004 psi at 6465'TVDss. Maximum anticipated surface pressure assuming gas in entire annulus (0.1 psi/ft) is 3357 psi. Maximum anticipated bottom hole pressure within the Sag River is -4000 psi at 8644'TVDss. Maximum anticipated surface pressure assuming gas in entire annulus (0.1 psi/ft) is 3135 psi. Maximum anticipated bottom hole pressure within the Ivishak Interval is -4400 psi at 8879'TVDss. Maximum anticipated surface pressure assuming gas in entire annulus (0.1 psi/ft) is 3512 psi. Hazards · Ugnu may be slightly overpressured due to water disposal at GC-2 which is 10.5 miles to the east. (Again, pressure will be determined from RFTs in NWE 1-01) · The Well path will cross four faults. These faults will be discussed within the well plan and measures will be taken to control lost circulation or other problems associated with drilling across the faults. · Based on offset well data, there are known accumulations of frozen gas hydrates in the area. Will apply knowledge gained from the NWE 1-01 well. (See attached discussion). ! The Kuparuk C Sand is potentially overpressured due to gas injection in the Kuparuk Operating Unit. Recent well data suggests that a pore pressure of 0.62 psi/ft is possible. RFTs from NWE1-01 will show more accurate data. Disposal Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal. NWE 2-01 Short Well Summary Rig Work: 1. MIRU. NU diverter and function test same. 2. Drill 16" hole vertically with MWD Directional/GR to -2772'MD/2700'TVDss below the in the T3 interval. Drill this interval with LSND mud system. Will weight up to 10.2 ppg and treat mud with lecithin prior to reaching the base of the permafrost. 3. Log surface hole interval with platform express and dipole sonic. 4. Run and cement 13-3/8" 68# L-80 casing to surface with a davis lynch screw-in system as per the recommended practices. 5. ND diverter, Install Blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Test BOPE to 250/5000 psi. ~ 6. RIH with bit, Test 13-3/8" casing to 3000 psi for 30 minutes. Drill out float equipment and shoe and 20' of new formation; perform a formation leak-off test using the BJ cement unit as per the SSD Leak off Test Procedure. (NWE 1-01 LOT resulted in a 13.3 ppg EMW) 7. Drill 12-1/4" hole directionally with MWD/GR/RES building to a 35° sail angle (2.5 °/100 dog legs) and then drill ahead -1700' of tangent before beginning a 2.5°/100 drop to 16 Deg Inclination. The well will be landed at <16° Inc. before entering the Kuparuk interval. Will displace the fluid system from LSND to KCI drilling fluid prior to entering the Kuparuk interval. 6. Core 8-1/2" hole (4" core) to obtain -60 feet of Kuparuk C sands. 7. Will ream out cored interval (from 8-1/2" to 12-1/4") and drill ahead 12-1/4" hole with MWD directional/GR/RES to just shy of the Sag river. 8. Run platform express logs on eline (GR/RES/Den/NEU). 9. Run DIPOLE SONIC on eline. 6 ') ) > ), CONFIDENTIAL 10. Run CMR logs on eline. 11. Run FMS on eline. 12. Plan to run SWC and RFTs if hydrocarbons are observed in the West Sak while drilling the intermediate hole section. 13. Make a clean out bit run to TD and prepare for running casing. 14. Run and cement 9-5/8" 47# L-80 casing to surface and cement using two stages as per the recommended practices with Class "G" cement in both stages. The first stage will bring cement to 1 000' above the Kuparuk D interval; the second stage will cover from 50' below the Kuparuk interval to 1000' above the Kuparuk interval. Bump the plug, confirm that the ES cementer is closed. 15. RIH with bit, Drill out float equipment and all casing internal jewelry to a few feet within the casing shoe. Test 9-5/8" casing to 3000 psi for 30 minutes. Clean up the coring KCI mud system to ensure that it is within the specs of the well program. Drill out shoe and 10' of new formation; perform a formation leak-off test as per the SSD Leak off Test Procedure. 16. Drill 8-1/2" hole to core point. 17. Core 8-1/2" hole (4" core) to obtain -60 feet of the Sag river sands. 18. Drill 8-1/2" tangent to the Ivishak core point. 19. Core 8-1/2" hole (4" core) to obtain -120 feet of Ivishak sands. 20. Drill 8-1/2" hole to TD of 1 0154'md or far enough below the base of the Ivishak interval to provide sufficient rat hole to run logs. 21. Run platform express logs on eline (GR/RES/Den/NEU). 22. Run DIPOLE SONIC on eline. 23. Run Numar logs on eline. 24. Run RFTs on eline. 25. Run and cement 7" 26# L-80 liner (150' of lap inside 9-518" casing). Test Casing. 26. Run and set a production packer with 3-1/2" L-80 tubing tail at the top Sag River (used to isolate Sag and Ivishak during well testing after rig departure). 27. Run 3-1/2" L-80 tubing completion with 3 GLMs and a 3-1/2" x 9-5/8" production packer set in the 9- 5/8" casing so that the tubing tail is -100' above the Kuparuk productive horizon. 28. Test tubing and annulus. Set TWC. 29. ND BOP, NU and test tree. 30. Pull TWC, freeze protect, set BPV, RDMO. 31. Well will be tested by PE group following rig release. 7 ,) ) ) ) 'CONFIDENTIAL North West Eileen 2-01 Pore Pressure I Fracture Gradients I Hazard Summary . Pore Pressure Review of seismic data in the vicinity of North West Eileen 2-01 (NWE 2-01) in conjunction with offset well records (mud logs, sonic logs) has indicated that no abnormal pressures are expected in the NWE 2-01 area aside from the Ugnu which has potentially been charged from produced water injection and the Kuparuk C sand interval which has potentially been overcharged from gas injection in the Kuparuk River Operating Unit (see additional comments below). The Ugnu sands are charged in many parts of Prudhoe Bay and the pore pressure is expected to be --9.0-9.2 ppg in that interval. An abnormal pressure of 0.62 psi/ft or 11.9 ppg EMW is potential' in the Kuparuk C sand interval due to gas injection. The over-pressure gradient originates from the Kuparuk River Unit gas injection strategy which originates at OS1-C. This overpressure in the Kuparuk River Unit C sands was confirmed most recently in the 1 C-12 and 1 C- 13 well drilled by the Arco Kuparuk drilling group. However, there is data which suggests that the faulting around the NWE 2-01 Bottom Hole Location is oriented in such a way that the Kuparuk horizon will be pressured more similarly to the Milne Point Kuparuk at H pad (.45 psi/ft) as opposed to the abnormally pressured Kuparak C sands within the Kuparuk River Unit. Results from the NWE 1-01 RFTs along with mud logging and sound drilling practices will all be used to safely and efficiently drill this section of the well. SSO is currently assuming that the interval can be drilled with mud weights similar to those used at Milne Point H Pad (10.2 ppg) through this interval. Mud weights which provide 100-200 psi overbalance will be used to ensure hydrostatic control. The Sag river interval is assumed to be at a maximum pore pressure of 4000 psi at 8644'tvdss (8.9 ppg EMW) while the Ivishak interval is expected to be at a maximum pore pressure of 4400 psi at 8879'tvdss (9.6 ppg EMW). The well is planned to TO at 9450'tvdss in order to provide sufficient rat hole to log the base of the Ivishak interval. . Fracture Gradient Information available from the offset wells have been reviewed to provide a best estimate of fracture gradients to be expected. 13-3/8" casing point (--2700' TVOss) should provide a fracture gradient of 12.2 - 13.5 ppg EMW. This leak off result will provide sufficient kick tolerance to drill to planned TO of the 12-1/4" hole section at base of the Kingak --8631 'tvdss (above Sag river) assuming a Kuparuk pore pressure of 8.6 ppg. The 9-5/8" casing point should provide a fracture gradient of 12.5 - 14.5 ppg EMW. This leak off result will provide sufficient kick tolerance to drill to planned TO of the 8-1/2" section at the base of the Ivishak --9450'tvdss. ) ) ¡. ) ~ONFIDENTIAL · Kick tolerance monitoring and pore pressure determination techniques Kick tolerance volume will be continually updated as the well is in progress, incorporating the most up-to-date data available from the well. The real-time resistivity log incorporated in the MWD assembly will enhance the mud logging crew's ability to monitor for change in pore pressure in addition to the normal techniques of D-Exp. projections, cuttings quality, connection gases etc. Shallow Gas and Shallow Gas Hydrate Analysis Based on review of a seismic traverse line that includes analogue wells Arco NW Eileen St #1, Mobil West Kuparuk St #1, and Socal 33-29E, no shallow gas pockets are expected on the North West Eileen 2-01 well. No seismic anomalies were seen at any of the three analogue wells or at the proposed ice pad NWE 2. However, the North West Eileen area does not have any high resolution seismic and offset data will therefore be used as the primary source to evaluate potential drilling hazards which could include shallow gas and/or hydrates. Based on review of offset drilling data, the potential to encounter hydrates while drilling surface hole at NWE 2-01 is high. Review of off-set well data reveals presence of hydrates near the base of the permafrost. The offset wells reviewed include NWE 1-01, Mobil West Kuparuk State #1 , NW Eileen State #1 & #2, West Sak 24, KRU 1 C-12, Prudhoe Bay Z pad, and Milne Point K pad. When a hydrate zone is encountered, the relative warmth of the drilling mud will decompose the hydrates and gasify the mud. The hydrates adjacent to the wellbore will continue to decompose and gasify the drilling mud as long as drilling operations continue to introduce heat into the hydrate-bearing interval. While encountering shallow hydrates has been known to cause severe problems in other parts of the world, this occurrence is well known and handled frequently at Prudhoe Z-Pad and Milne Point. The use of high density mud weight (,...,10.2 ppg) and the additive Lecithin, are two proactive safety measures that will be employed in the drilling operation. Data from off-set wells shows gas hydrates to most likely exist at the base of the permafrost in several layers beginning at 1500' tvd to 2450' tvd with a total thickness of 171 ' to 349'. The base of the permafrost in NWE 2-01 is expected to be ,...,1700' tvdss. Operating procedure will be to add Lecithin to the drilling fluid when gas cut mud is found by the mud logger. The mud weight will continually increase from 8.6 ppg at spud to 10.2 ppg at ,...,1600' tvd and remain so until surface hole TD. These actions continually prove to be sufficient when gas hydrates are encountered at Milne Point and Prudhoe Z-Pad and were successful in controlling hydrates in the NWE 1-01 surface hole interval. Pool 8 will also be equipped with the following gas detection systems as a proactive measure to monitor shallow gas and/or hydrates: ) ) \; / · Rig gas sensors located at the pits, cellar, & rig floor · PVT system · Trip tank · Well Mud Loggers - Specialized personnel - Total Hydrocarbon Analyzer (FID) - Gas Chromatogragh (FID) ') CONFIDENTIAL Usual SSD procedures will be followed to minimize any potential for a shallow gas kick. Sufficient hydrostatic column will always be maintained while drilling the well and the correct tripping procedures will be followed while tripping in and out of the hole. If a shallow gas kick is taken prior to setting surface casing, the gas kick will not be shut-in, but diverted through the diverter system. If you have any questions, please give me a call at 564-4803. 1000 2000 3000 =- 4000 --- = C ¡:: oS 5000 Q. ~ 6000 7000 8000 9000 ) ) ') / ) CONFIDENTIAL North West Eileen 2-01 Anticipated Pore Pressure/Mud WeightlFracture Gradient ~'IIII ¡: '\,,\\, ·'·'i~ii:: 1',ta::;I:' , aise ,iò~I:,YVeig It 1J1I, or Hydrateà'il!li", '1'.111:1 ~i"':'~';:'i':')'i:~:~i:1 ! \Iil :;:1,: i:I::~ 13-3/8" 'II ,i:!:'" casing point :,III!I'--- (2700'tvdss) ii:~!" j~II' t;¡;( I]': ,1:'1' I ,'i::~j:I' lil¡i~\ l ¡,~I.( ,,(f Planned Mud ,1::~ W . ht ~'~'~':'I :ll::¡, , ~ I 9 """.'" ijl, ~- ~: 8 o 9 ppg EMW 11 12 10 '- "'-.. ,-- --. "' ' -.. "' p---- ~~ ~ 9-5/8" casing point (8631'tvdss) f'..C....CC"~.C~""C,..,',,"""'C,.,,:'; 1,.··.'..".,...01.,,·.&......·...,. I' .¡ I (~~..::.~.)~~~;J,¡~~~:\' ,I,! \~, ~ 13 14 15 Min. I-rac ~rad , -- -.. -.. , I , I I '~ I , Max ~rac Grad I , I , I , I , I , , I , , , , · \ · , · ) ) ) ) Attachment 1 Completion Diagram Approx depth ft md brt I I X nipple 300' L GLM 1 3000' 1 3-3/8" 2700' tvdss 3 112" tubing 2772'md L GLM 2 6800' L GLM3 6850' --::::::-'" ..><: Production packer 6900' .e- ~ ~ X nipple 6930' I Kuparuk perfs --- ~ WD packer 7500' 3 112" tailpipe K Z 9 5/8" shoe 9-5/8" L ~ 8644' tvdss ~ ~ XN nipple 9250' 9313'md I Sag perfs 7" 9450' tvdss / 10154' md \ 7" shoe CONFIDENrr~~' :il~II¡'t -', '1.11' ,:,~" :',: \~ ~, '~'e\R:r~ i ð~~~1\r8.' 3~¥2?8ð WD I 3000 5ectJon AzImuth: ~7 J1dr (True North) I I 1000 2000 Vertical Section I o Scale: 1 Inch ..1000ft j 3 en § .::::;::::'::::::::::::::::::::"''';'';;'''';;'''';:;:",,:::::::::::;t~;~~~:;~:~' 8716.00 TVD '; 9000 _. ...........................:::::::::::::::::.::........................ .'t.Q.ljl;.P~M-~;:fU.m..8951.ooIITVD NWE 02'(~ ri:~i~)" 8eOÓ.ÕÕ..·.... ........ .:;¡;-a:...:. :Ë ,............... 1061.00 1VO. 2104.Zt No ID31.3O E - I.............................::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::.. :::::::::: :::::::::::::::: ~ 4000 - 8000 - ,.......................................................................................................................................... ,.......................................................................... -rtflKtrt1e/l 7000 - .................................. ......O'.. ....... ... ...... ...... ...... ............. ........ ....... ... ....... ......... ............ ......................................................................................................................................................................................... «&pIIUIrA ........ ......... ....... .... .... ... ..... ..... .... "~:..:¡ .r.:r.~rp.o.t.!~~.~~R'!~~.~'! !l.! ~;~~~:.:.~?=ytf2. 6537.ooft TVD ....... .......... ........ .... '~w:artf:tT.a"(2OaR ......... ...... ................ .... "'_C ........ ................ ..... ..enz.og.W : Jltq·J!l!.:6J!H. .. .,200W.......... ..................... "'_O/LCUI 6000 - ................ ................... ..................". ........ ....... ...... ....... ......... ...... "'.. 8600.00 ,....... ........ ........ ....... ............. ......................................................·········«·'0 .t:: Õ. 8 B '€ 5000 - ~ ........................................................................«." .~f!C! J:!I!, ¡;.~l.~. ~~,1~?:.:.1~M9!tMI? ~m!,~<¡I}.1YJ:!..... ...... ........ "'.,._ I"~ l Iw:J~iE eN.led By: 72.00 ft RKB . AM~L Chtoked Oy : NA027 ~~~'u~":¡ Approved By: ~.By"'m: PLOT DATE: 02/12/98 ::P~ {) II~--~~j _... CoonInatoa: R(Ø EflVadon: SURFACE LOCATION 1710. Ie N, "',&3 E UI&3DO.OO N. 57'010.00 E 214<4,28 N. '0311.30 E 1v.l1711O.00 N. 671700.00 E TARGET 1 TARGET 2 1VOSB TVDRKB: _.00 0&37,00 1178,00 1115'.00 · 3000.00 3000 - Tara_t Nam. : GIoboI Coord""I.. : WallhudOffIlIl: J ~gf~~a~~~n~ ~~&f.~1ggft ~~~~ff~. ~.OOft TVD PROPOSAL TARGET SUMMARY · 2400.00 ....... ...... .......... ...... ... ..... .......... ..... ............ ................ ..... ..... ........ ."f(." ............. .......................................................................................7:1 2000 - ........... ...., aOO:dc1·..·......··...... ....... ........... ......... ................................-- ~.: WaoII WaoII ft NorIIRoI_: T..._ ==~: ~porl00ft v_Seetlon o-IpIon: WaoII v_ _00tcIin: 0,00 N.O.oo E - InaI. - Vutloal -..ne. Eøllng_ v....... ~: Dap4h DapIh Seel'" 0,00 0,000 0.5'1 0,00 O.ooN O.OOB 0,00 0,000 2772,00 0.000 0.541 2772.00 O,OON o,OOB 0,00 1131.00 0,000 0.5011 2I3~00 O.OON O.OOB 0.00 0,000 '231," 25,1" 8,2.W 41.51.10 ..11.IS'N 67.20 B 285.82 ~500 5...5.02 25.151 8.2.W 5507... 13111.11N 22.532B 1226,11 0,000 702.... 16.652 9.113 6537.00 171O.IISN "¡".UB 1706.57 ~500 .551,52 16.651 '8.712 11951.00 :n....29N IOJUO B 2310.75 0,000 101Sol.'1 16.651 W,712 0522.00 W'U2N 1115,77B 2526,02 0,000 · 1200.00 1000 - · 600.00 Propo..' D.r. for NWe: 02·01 WP3 0- DrillQues( Shared Services Drilling Well: NWE 02-01 WP3 spel""'l""'y-sun OFltL.L.INCI SIiAV'Cø. ) 1> ,) u ') ) (It speJ""l""y-sun gRIL.L.INCII S&RVIC"'. .-- 1/1 œ c 1200 - € o z \Y ') Scale: 11nch . 400ft o I 2400 - 2000 - 1600 - 5700.00 , 5400.00 , , 5100.00 , 4800.00 , 800 - 4500.00 , 4200.00 , 400 - ) - ") Shared Services Drilling Well: NWE 02-01 WP3 Eastlngs 400 800 I I 1200 , - 2400 )CONFID DrillQuesf 7' Uner-10154.51 MD,9522.00TVD Toal Depth: 10154.5111 MD, 9522.00IlTVD - 2000 - 1600 ...........Start Dlr 0 2.500'/10011: 5945.4311 MD, 5547,4011 TVD UI œ - 1200 c € o z - 800 '-...end Dlr, Sail 0 35.157': 4238.3011 MD, 4151.701lTVD -400 3800.00 .. o - '" KOP: Start Dlr 0 2.500'/1001I: 2832.0011 MD, 2832.00 TVD 13318' Casing - 2m.00 MD, 2m.00 TVD 'NtISS TVDRICB: PROPOSAL TARGET SUMMARY 1110.1' N. 414..13 E 21_N,1~E T_ Nome: TARGET' T AAGE'T 2 -... 0537,00 117'1.00 1051.00 W_OIIoooIo: I o Scale: 11nch . 400ft -~: 5_00 N, 571010.00 E 5_7",00 N, 571700.00 E :,:~q. .': ",··1 -0 I I I 400 800 1200 Eastlngs Reference Is True North SURFACE LOCATION PLOT DATE: 02/12/98 ==-~: 5ær~~=::: ~~ c-IrwoSyum: NAD27~~= ~Øy: :~ ';.' ~, ¡ Sperry-Sun Drilling Services Proposal Report for NWE 02-01 . NWE 02-01 WP3 AK Exploration Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Inel. Azlm. Depth Depth Northlngs Eastings Northings Eastlngs (ft) (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -72.00 0.00 O.ooN O.ooE 5986606.00 N 570682.00 E 100.00 0.000 0.000 28.00 100.00 O.ooN O.ooE 5986606.00 N 570682.00 E 200.00 0.000 0.000 128.00 200.00 O.ooN O.ooE 5986606.00 N 570682.00 E 300.00 0.000 0.000 228.00 300.00 O.ooN O.ooE 5986606.00 N 570682.00 E 400.00 0.000 0.000 328.00 400.00 O.ooN O.ooE 5986606.00 N 570682.00 E 500.00 0.000 0.000 428.00 500.00 O.ooN O.ooE 5986606.00 N 570682.00 E 600.00 0.000 0.000 528.00 600.00 O.ooN O.ooE 5986606.00 N 570682.00 E 700.00 0.000 0.000 628.00 700.00 O.ooN O.ooE 5986606.00 N 570682.00 E 800.00 0.000 0.000 728.00 800.00 O.ooN O.ooE 5986606.00 N 570682.00 E 900.00 0.000 0.000 828.00 900.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1000.00 0.000 0.000 928.00 1000.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1100.00 0.000 0.000 1028.00 1100.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1200.00 0.000 0.000 1128.00 1200.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1300.00. 0.000 0.000 1228.00 1300.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1400.00 0.000 0.000 1328.00 1400.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1500.00 0.000 0.000 1428.00 1500.00 0.00 N O.OOE 5986606.00 N 570682.00 E 1600.00 0.000 0.000 1528.00 1600.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1700.00 0.000 0.000 1628.00 1700.00 0.00 N O.ooE 5986606.00 N 570682.00 E 1772.00 0.000 0.000 1700.00 1772.00 O.ooN O.ooE 5986606.00 N 570682.00 E --",..~ 1800.00 0.000 0.000 1728.00 1800.00 O.ooN O.ooE 5986606.00 N 570682.00 E 1900.00 0.000 0.000 1828.00 1900.00 0.00 N O.ooE 5986606.00 N 570682.00 E 2000.00 0.000 0.000 1928.00 2000.00 O.ooN O.ooE 5986606.00 N 570682.00 E 2100.00 0.000 0.000 2028.00 2100.00 O.ooN O.ooE 5986606.00 N 570682.00 E 2187.00 0.000 0.000 2115.00 2187.00 O.ooN O.ooE 5986606.00 N 570682.00 E 2200.00 0.000 0.000 2128.00 2200.00 O.ooN O.ooE 5986606.00 N 570682.00 E 2300.00 0.000 0.000 2228.00 2300.00 O.ooN O.ooE 5986606.00 N 570682.00 E 2400.00 0.000 0.000 2328.00 2400.00 O.ooN O.OOE 5986606.00 N 570682.00 E 2477.00 0.000 0.000 2405.00 2477.00 O.ooN O.ooE 5986606.00 N 570682.00 E 2500.00 0.000 0.000 2428.00 2500.00 O.ooN O.OOE 5986606.00 N 570682.00 E 2600.00 0.000 0.000 2528.00 2600.00 O.ooN O.ooE 5986606.00 N 570682.00 E 12 February, 1998 - 15:04 - 1- :: Alaska State Plane Zone 4 NWE Dogleg Vertical Rate Section Comment (o/10Oft) (ft) 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 Base Permafrost T3 K-15 c-:> c::> ::2!: . -n - c:::J . m ..··";,;~:~~~!~~~·~t:~¥,~4i;;:è3gìii:";¿~~~~ë~~~",ê{;~~~~~{*flf~~~?!#I)~~~f~l!i~~~~i1 ,~~ --- Ii ~) --'" Continued... DrillQuest _. 'iik1i II Sperry-Sun Drilling Services Proposal Report for NWE 02-01 - NWE 02-01 WP3 Alaska State Plane Zone 4 AK Exploration NWE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) eNOOft) (ft) 2700.00 0.000 0.000 2628.00 2700.00 O.OON O.OOE 5986606.00 N 570682.00 E 0.000 0.00 '-"'" 4 2772.00 0.000 0.000 2700.00 2772.00 O.OON O.OOE 5986606.00 N 570682.00 E 0.000 0.00 13318" Casing 2800.00 0.000 0.000 2728.00 2800.00 O.OON O.OOE 5986606.00 N 570682.00 E 0.000 0.00 2832.00 0.000 0.000 2760.00 2832.00 O.OON O.OOE 5986606.00 N 570682.00 E 0.000 0.00 KOP : Start Dir @ 2.5000/100ft : 2832.00ft MD, 2832.00ft TVD 2900.00 1.700 9.254 2827.99 2899.99 1.ooN 0.16 E 5986607.00 N 570682.15 E 2.500 0.96 -" 3000.00 4.200 9.254 2927.85 2999.85 6.07N O.99E 5986612.08 N 570682.93 E 2.500 5.83 3100.00 6.700 9.254 3027.39 3099.39 15.45 N 2.52E 5986621.47 N 570684.37 E 2.500 14.82 3200.00 9.200 9.254 3126.42 3198.42 29.10 N 4.74E 5986635.14 N 570686.47 E 2.500 27.92 3300.00 11.700 9.254 3224.75 3296.75 47.00 N 7.66E 5986653.07 N 570689.21 E 2.500 45.09 3400.00 14.200 9.254 3322.20 3394.20 69.11 N 11.26 E 5986675.22 N 570692.61 E 2.500 66.31 3500.00 16.700 9.254 3418.58 3490.58 95.41 N 15.54 E 5986701.55 N 570696.64 E 2.500 91.54 3600.00 19.200 9.254 3513.71 3585.71 125.82 N 20.50 E 5986732.01 N 570701.31 E 2.500 120.72 3700.00 21.700 9.254 3607.40 3679.40 160.30 N 26.12 E 5986766.54 N 570706.60 E 2.500 153.80 3800.00 24.200 9.254 3699.47 3771.47 198.78 N 32.39 E 5986805.08 N 570712.51 E 2.500 190.73 3900.00 26.700 9.254 3789.76 3861.76 241.19 N 39.30 E 5986847.55 N 570719.02 E 2.500 231.42 4000.00 29.200 9.254 3878.09 3950.09 287.45 N 46.84 E 5986893.88 N 570726.12 E 2.500 275.80 4100.00 31.700 9.254 3964.29 4036.29 337.47 N 54.98 E 5986943.97 N 570733.79 E 2.500 323.78 4160.09 33.202 9.254 4015.00 4087.00 369.29 N 60.17 E 5986975.84 N 570738.68 E 2.500 354.32 K-13 (Schr) CI 4200.00 34.200 9.254 4048.20 4120.20 391.14 N 63.73 E 5986997.73 N 570742.03 E 2.500 375.29 4238.30 35.158 9.254 4079.70 4151.70 412.65 N 67.24 E 5987019.27 N 570745.33 E 2.500 395.93 End Dir, Sail @ 35.157°: 4238.300 MD, 4151.700 TVD 4300.00 35.158 9.254 4130.14 4202.14 447.72 N 72.95 E 5987054.39 N 570750.72 E 0.000 429.57 4400.00 35.158 9.254 4211.90 4283.90 504.55 N 82.21 E 5987111.31 N 570759.44 E 0.000 484.10 4434.37 35.158 9.254 4240.00 4312.00 524.09 N 85.39 E 5987130.87 N 570762.44 E 0.000 502.84 K-12 ~ 4500.00 35.158 9.254 4293.65 4365.65 561.38 N 91.47 E 5987168.22 N 570768.16 E 0.000 538.63 4600.00 35.158 9.254 4375.41 4447.41 618.22 N 100.73 E 5987225.14 N 570776.88 E 0.000 593.16 4700.00 35.158 9.254 4457.17 4529.17 675.05 N 109.99 E 5987282.06 N 570785.61 E 0.000 647.68 4800.00 35.158 9.254 4538.93 4610.93 731.88 N 119.25 E 5987338.98 N 570794.33 E 0.000 702.21 .~ 4900.00 35.158 9.254 4620.68 4692.68 788.72 N 128.51 E 5987395.90 N 570803.05 E 0.000 756.74 5000.00 35.158 9.254 4702.44 4774.44 845.55 N 137.77 E 5987452.82 N 570811.78 E 0.000 811.27 5076.52 35.158 9.254 4765.00 4837.00 889.04 N 144.85 E 5987496.37 N 570818.45 E 0.000 853.00 K-10 Continued... 12 February, 1998 - 15:04 C J DrlllQuest c:::> ~ H"~_'.......,,'.,. , :-............;.- .ì~:i];:~~~~:;.:...:.::-:'·.:: , :;.æ........... . ,....:;.,.;~~t~ø.~~~i{#J,;~~ -2- ,.. .," ..._~-~.--....-,- ~...:::.: .1,.... ...... ',' ...~.. ~"_ . ,,',' ~ !'~...~ ':~ ;"~~.....~..~._;"~:~~"~ :.~ . . ~~..... .,;:,--...-~~~--;-::..=:;-~'~~::::?~~~.~"':'.- .. , ~. :..: -:. -, .' .;. ,,"" -' !~. .'- .. ----. . .... __ . ~_ ._' _.0.. _," _ '__ _. , Sperry-Sun Drilling Services Proposal Report for NWE 02-01 - NWE 02-01 WP3 Alaska State Plane Zone 4 AK Exploration NWE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) (ft) 5100.00 35.158 9.254 4764.20 4856.20 902.38 N 147.03 E 5987509.73 N 570820.50 E 0.000 865.80 -./(ß 5200.00 35.158 9.254 4865.95 4937.95 959.22 N 156.29 E 5987566.65 N 570829.22 E 0.000 920.33 5300.00 35.158 9.254 4947.71 5019.71 1016.05 N 165.55 E 5987623.57 N 570837.94 E 0.000 974.86 5400.00 35.158 9.254 5029.47 5101.47 1072.88 N 174.81 E 5987680.49 N 570846.67 E 0.000 1029.39 5500.00 35.158 9.254 5111.23 5183.23 1129.72 N 164.07 E 5987737.41 N 570855.39 E 0.000 1083.92 '----' 5600.00 35.158 9.254 5192.98 5264.98 1186.55 N 193.33 E 5987794.32 N 570864.11 E 0.000 1138.45 5700.00 35.158 9.254 5274.74 5346.74 1243.38 N 202.59 E 5987851.24 N 570872.64 E 0.000 1192.98 5749.24 35.158 9.254 5315.00 5387.00 1271.37 N 207.15 E 5987879.27 N 570877.13 E 0.000 1219.83 K-5 5800.00 35.158 9.254 5356.50 5428.50 1300.22 N 211.85 E 5987908.16 N 570881.56 E 0.000 1247.51 5900.00 35.158 9.254 5438.25 5510.25 1357.05 N 221.11 E 5987965.08 N 570890.28 E 0.000 1302.04 5945.43 35.158 9.254 5475.40 5547.40 1382.87 N 225.32 E 5987990.94 N 570894.24 E 0.000 1326.81 Start Dir @ 2.5000/100ft: 5945.43ft MD, 5547.4Oft TVD 6000.00 33.967 10.429 5520.33 5592.33 1413.37 N 230.60 E 5988021.49 N 570899.24 E 2.500 1356.22 6100.00 31.818 12.781 5604.30 5676.30 1466.56 N 241.49 E 5988074.78 N 570909.63 E 2.500 1408.30 6200.00 29.717 15.432 5690.23 5762.23 1516.17 N 253.92 E 5988124.50 N 570921.59 E 2.500 1457.94 6300.00 27.676 18.441 5777.94 5849.94 1562.10 N 267.86 E 5988170.56 N 570935.10 E 2.500 1505.04 6400.00 25.710 21.880 5867.29 5939.29 1604.27 N 283.30 E 5988212.87 N 570950.13 E 2.500 1549.51 6485.68 24.098 25.232 5945.00 6017.00 1637.34 N 297.68 E 5988246.08 N 570964.20 E 2.500 1585.47 K-2 . ~.-. 6500.00 23.836 25.834 5958.09 6030.09 1642.59 N 300.19 E 5988251.35 N 570966.66 E 2.500 1591.28 lit ~;-...::¡¡ 6600.00 22.079 30.398 6050.17 6122.17 1676.99 N 318.51 E 5988285.93 N 570964.65 E 2.500 1630.25 6700.00 20.469 35.674 6143.36 6215.36 1707.41 N 338.21 E 5988316.53 N 571004.07 E· 2.500 1666.37 6800.00 19.043 41.755 6237.48 6309.48 1733.79 N 359.28 E 5988343.11 N 571024.89 E 2.500 1699.55 6900.00 17.845 48.698 6332.36 6404.36 1756.08 N 381.66 E 5988365.60 N 571047.06 E 2.500 1729.73 6970.92 17.161 54.139 6400.00 6472.00 1769.38 N 398.30 E 5988379.06 N 571063.57 E 2.500 1749.29 Kuparuk D Shale ~~- 7000.00 16.925 56.485 6427.80 6499.80 1774.23 N 405.31 E 5988383.98 N 571070.53 E 2.500 1756.86 7038.86 16.652 59.713 6465.00 6537.00 1780.16 N 414.83 E 5988390.00 N 571080.00 E 2.500 1766.57 k~g:~h~nd Dir. Sail @ 16.652°: 7038.86ft MD, 6537.00ftTVD Target: NWE 02-01 T1, 200.00 Radius. Geological .---- 12 February, 1998 -15:04 -3- CJ c:::) :::;2!: --n - c:::J rn· :z: ~ -:-----.......-----.-....-..-..-:..:->--.<----.....-----.--.".'-"."._,".- . - ~ "3~,,;I';'~~"":;''i.,;~~r~~ê~td!~t1£i~;;,;;;;'itf'·,;'; ..... ".' . .:"'..::..~~-;:~,~:~..':.;_~.'S.:...-;¡.,;.:.;~-:.:.-.' .' ::...:. . . ... ConUnued... Dri/lQuest - - - -- - - --- - - - -. -.~- ~-,-:-:,--_--·--------:~t~~ .. . -. _.-.-------'----. .' .,~ c,s:@,~ ...,-....:.::'."'::' ._~ -;~ ..~---------. 'J;'*~~~~;, ..:. '-.' ..'- .~.........;.~...~ AK Exploration Measured Sub-Sea Vertical Depth Incl. Azlm. Depth Depth (ft) (ft) (ft) 7100.00 16.652 59.713 6523.58 6595.58 7174.55 16.652 59.713 6595.00 6667.00 7200.00 16.652 59.713 6619.39 6691.39 7300.00 16.652 59.713 6715.19 6787.19 7344.68 16.652 59.713 6758.00 6830.00 7400.00 16.652 59.713 6811.00 6883.00 7451.15 16.652 59.713 6860.00 6932.00 7500.00 16.652 59.713 6906.81 6978.81 7600.00 16.652 59.713 7002.61 7074.61 7700.00 16.652 59.713 7098.42 7170.42 7800.00 16.652 59.713 7194.22 7266.22 7900.00 16.652 59.713 7290.03 7362.03 8000.00 16.652 59.713 7385.84 7457.84 8089.93 16.652 59.713 7472.00 7544.00 8100.00 16.652 59.713 7481.64 7553.64 8200.00 16.652 59.713 7577.45 7649.45 8300.00 16.652 59.713 7673.26 7745.26 8400.00 16.652 59.713 7769.06 7841.06 8500.00 16.651 59.713 7864.87 7936.87 8600.00 16.651 59.713 7960.68 8032.68 8700.00 16.651 59.713 8056.48 8128.48 8800.00 16.651 59.713 8152.29 8224.29 8900.00 16.651 59.713 8248.10 8320.10 9000.00 16.651 59.713 8343.90 8415.90 9100.00 16.651 59.713 8439.71 8511.71 9200.00 16.651 59.713 8535.52 8607.52 9300.00 16.651 59.713 8631.32 8703.32 9313.24 16.651 59.713 8644.00 8716.00 9359.16 16.651 59.713 8688.00 8760.00 9400.00 16.651 59.713 8727.13 8799.13 12 February, 1998 - 15:04 ~ ~J Sperry-Sun Drilling Services Proposal Report for NWE 02-01 - NWE 02-01 WP3 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Vertical Rate Section Comment CO/100ft) (ft) 1789.00 N 429.96 E 5988398.98 N 571095.05 E 0.000 1781.47 1799.77 N 448.41 E 5988409.93 N 571113.39 E 0.000 1799.64 1803.45 N 454.71 E 5988413.66 N 571119.65 E 0.000 1805.85 1817.90 N 479.45 E 5988428.35 N 571144.26 E 0.000 1830.23 1824.36 N 490.51 E 5988434.91 N 571155.25 E 0.000 1841.12 1832.35 N 50420 E 5988443.03 N 571168.87 E 0.000 1854.60 1839.74 N 516.85 E 5988450.54 N 571181.45 E 0.000 1867.07 1846.81 N 528.94 E 5988457.72 N 571193.47 E 0.000 1878.98 1861.26 N 553.68 E 5988472.40 N 571218.08 E 0.000 1903.35 1875.71 N 578.43 E 5988487.09 N 571242.69 E 0.000 1927.73 1890.16 N 603.17 E 5988501.77 N 571267.29 E 0.000 1952.11 1904.61 N 627.92 E 5988516.46 N 571291.90 E 0.000 1976.48 1919.06 N 652.66 E 5988531.14 N 571316.51 E 0.000 2000.86 1932.06 N 674.91 E 5988544.35 N 571338.64 E 0.000 2022.78 1933.51 N 677.41 E 5988545.83 N 571341.11 E 0.000 2025.23 1947.97 N 702.15 E 5988560.51 N 571365.72 E 0.000 2049.61 1962.42 N 726.89 E 598857520 N 571390.33 E 0.000 2073.98 1976.87 N 751.64 E 5988589.88 N 571414.93 E 0.000 2098.36 1991.32 N 776.38 E 5988604.56 N 571439.54 E 0.000 2122.74 2005.77 N 801.13 E 5988619.25 N 571464.15 E 0.000 2147.11 2020.22 N 825.87 E 5988633.93 N 571488.75 E 0.000 2171.49 2034.67 N 850.61 E 5988648.62 N 571513.36 E 0.000 2195.86 2049.13 N 875.36 E 5988663.30 N 571537.97 E 0.000 2220.24 2063.58 N 900.10 E 5988677.99 N 571562.57 E 0.000 2244.61 2078.03 N 924.84 E 5988692.67 N 571587.18 E 0.000 2268.99 2092.48 N 949.59 E 5988707.35 N 571611.78 E 0.000 2293.36 2106.93 N 974.33 E 5988722.04 N 571636.39 E 0.000 2317.74 2108.84 N 977.61 E 5988723.98 N 571639.65 E 0.000 2320.96 2115.48 N 988.97 E 5988730.73 N 571650.95 E 0.000 2332.16 2121.38 N 999.08 E 5988736.72 N 571661.00 E 0.000 2342.11 -4- Kuparuk B (LCU) Kuparuk A Miluveach Top Kingak f~8S~a~~~r Shublik . ,. .. . . .- Alaska State Plane Zone 4 NWE ~/E '-' G F-::~~ - ~ Continued... DrlflQuest c-:> c::> . .....'".-,.'"....__......'"..~..."""'"...-h~-.< ':"/ri" ----- :; ~.' .',.,.. J: .,',..~~. . -.'. -' ,'-' '. I""""'r'"'I .. . " ':: ' :', ,. -",'.'.' '.," '.-'~:., . , "-.:/ "', ..........:.,..~..-.:,...,.:.'.....,., :'Y··;i;;"~.#~!!~ Sperry-Sun Drilling Services Proposal Report for NWE 02-01 . NWE 02-01 WP3 Alaska State Plane Zone 4 .. AK Exploration NWE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ol100ft) (ft) 9500.00 16.651 59.713 8822.94 8894.94 2135.83 N 1023.82 E 5988751.41 N 571685.60 E 0.000 2366.49 ~)~ 9518.85 16.651 59.713 8841.00 8913.00 2138.56 N 1028.48 E 5988754.18 N 571690.24 E 0.000 2371.08 Top Eileen 9558.52 16.651 59.713 8879.00 8951.00 2144.29 N 1038.30 E 5988760.00 N 571700.00 E 0.000 2380.75 targ~ãt~~\52ft MD, 8951.00ft TVD T~t: NWE 02-01 T2, 200.00 Radius. Geological 9600.00 16.651 59.713 8918.74 8990.74 2150.28 N 1048.56 E 5988766.09 N 571710.21 E 0.000 2390.86 ~ 9700.00 16.651 59.713 9014.55 9086.55 2164.74 N 1073.31 E 5988780.78 N 571734.81 E 0.000 2415.24 ~ - . -' . 9776.66 16.651 59.713 9088.00 9160.00 2175.81 N 1092.28 E 5988792.03 N 571753.68 E 0.000 2433.93 - T27P . -.~-"o....:..;..:. 9800.00 16.651 59.713 9110.36 9182.36 2179.19 N 1098.05 E 5988795.46 N 571759.42 E 0.000 2439.61 9870.60 16.651 59.713 9178.00 9250.00 2189.39 N 1115.52 E 5988805.83 N 571776.79 E 0.000 2456.82 -T26N ~ 9900.00 16.651 59.713 9206.16 9278.16 2193.64 N 1122.79 E 5988810.14 N 571784.02 E 0.000 2463.99 ~~y 10000.00 16.651 59.713 9301.97 9373.97 2208.09 N 1147.54 E 5988824.83 N 571808.63 E 0.000 2488.36 10100.00 16.651 59.713 9397.78 9469.78 2222.54 N 1172.28 E 5988839.51 N 571833.24 E 0.000 2512.74 10154.51 16.651 59.713 9450.00 9522.00 2230.42 N 1185.77 E 5988847.52 N 571846.65 E 0.000 2526.02 Total Depth: 10154.51ft MD, 9522.00ft TVD 7" Uner .'"=:!~~ All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 27.997° (True). I - - Based upon Minimum Curvature type calculations, at a Measured Depth of 10154.51ft., The Bottom Hole Displacement is 2526.02ft. in the Direction of 27.997° (True). ._~ ~ -, p-. . ..- ~~ . ....... ".-" - - ,- .. ..- " ...~..... .........._~........ ..... . - "-. ....~....... - "" . , ," . ~ ..... -..... ::-~-:?}~:~~f¡::~ - . -. -5- DrlllQuest 12 February, 1998·15:04 .. ,........--..-..... '-. _. .. .... . . -. "."." -"- .--., .... ~ - - .- ~ :: '<c ,,-,~ ') \ ) ". ~-oo~o' TONY KNOWLES, GOVERNOR ALASIiA OIL Alft) GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501·3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 23. 1998 John R. Denis PEU New Business De\'clopment BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage. AK 9<)519-6612 Subject: PBU NW Eileen Appraisal Wells - Surface Commingling of Test Production from Wells NWE 1-01. 1-02. 1-01 and 2-01 Dear Mr. Denis: The Commission received your letter dated Janmu~' I-k 19Y8. requesting permission to commingle Kuparuk Pool production from the Kuparuk formation with IP A production from the Prudhoe Pool during test operations. Your request is for surface commingling only and that there will be no downhole commingling of form<ltion fluids from the formmions comprising the Prudhoe Pool. Production from NWE I -0 I. 1-02. 1-01 and 2-0 I should be reported sepamtcly to the Prudhoe Bay Field. Kup<lruk River Pool (CO 9XA. pool number 6~O I ~O) during the test period. Production from N\VE 2-01 Saglh'ishak formations should be reported to the Pmdhoe Pool (pool number 6~O 150) for those months the well is on test. Attached is a summary of the standard allocation procedures for commingling fluids from sepamte pools. These procedures have been de\'eloped Q\'er the last several years and can serve as a guideline for allocating the fluids from the test operations, Disregard paragraph (c). regarding NGL allocation. until such time the wells are placed on regular production. A minimum of two tests per month is required during those months the wells are produced. We look forward to hearing results of the test. If there any questions regarding commingling or reporting procedures. contact Jack Hartz at 279-1433 ext. 232. ~ n Commission Attachment c: K. Boyd. DNRfDOG J, Pilkinton. DOR \\VE~onUll.doc ') l, " Surfncc CommlOclin1! ;Ind COlllmon F:lcilities a. Production from the Schrnder BlufT Undefined oil pool l11ay be commingled on the surÙ1ce ,Ùth production from other pools for processmg at PBU GC facilities prior to cllstod~' trnnsfer. b. Production from each well ,nil be detenmned by the following well tcst allocmion methodology. Allocation data and well tcst data will be supplied to the Commission monthl~' in both computer file and report formats. 1. Conduct well tests to dctenmne production rates for each well. ii. Calculate each well's theoretical monthly production (TMP) bnsed on well test rate(s) and actual time on production, iii. Sum the TMP volume for all wells in all pools. IV. Determine an allocal1on factor as thc ratio of the metered volume to the TMP for all wells in all pools (i ,e.. 1l1etered/r~ 1P) V. Calculate cach well's actual monthly production (AMP) volume as: AMP = TMP x Allocmion Factor c. NGL's will be allocated to each pool based on actual gas production volumes and NGL process simulations. Process simulations will be updated at least once per year bascd on NGL samples and results reported to the Commission. d. Each producing well ,Yill be tested at least twice each 1110nth. \Vells that h¡]ve been shut in and cannot meet the twice-monthly test frequency must be tested within [i"e days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. c. Optimum test duration and stabilin1tion time will be determined on a well by well basis by the operator. f. Water volumes will be determined by APIIMPMS approved methods. or the use of industry proven on-line water cut measurement devices approved by the Commission. g. API gra\'Ìty will be determined for each producing well annually by an APIfMPMS approved method. h. Gas samples ,yill be taken and nnalyzed for composition from ench non gns lifted producing well yearly. " ) ) BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 15, 1998 David W. Johnston, Chairman and Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ",;:~ ..~":';üil Request for Exception to the Provisions of 20 AAC 25.055 for the NWE 2-01 Dear Chairman Johnston: BP Exploration (Alaska), Inc. ("BPX") hereby applies for an exception to the provisions of 20 AAC 25.055 for the drilling of the NEW 2-01 Well (the "WeW). Relevant location data for the Well is as follows: (1) Suriace Location: 0453 ft. FSL, 0284 ft. FEL, Section 19, Township 12N, Range 11 E, UM on Chevron/Mobil oil and gas lease ADL04 7446. (2a) Hole Location top of Kuparuk interval: 2233 ft. FSL, 0137 ft. FWL, Section 20, T12N, R11 E UM on Chevron/Mobil oil and gas lease ADL047446. (2b) Bottom Hole Location top of Ivishak/Sag interval: 2597 ft. FSL, 0761 ft. FWL, Section 20, T12N, R11 E UM on Chevron/Mobil oil and gas lease ADL047446. (3) Total Depth: 9150 ft. SS TVD The owners and operators of all governmental quarter sections directly and diagonally offsetting the proposed location of the Well are Chevron U. S. A. Inc. and Mobil Alaska E&P Inc. The plat required by the regulation is attached as Exhibit 1. The verification required by the regulation is attached as Exhibit 2. Copies of the notifications to the owners and operators. as weìl as the required information with respect to mailing are attached in the package designated as Exhibit 3. ) ) . . David W. Johnston January 15, 1998 Page 2 If you have any questions or require any additional information, please contact Stu Hirsh at our letterhead address or at 564-4841. Sincerely, ,d/UJ ./lÞ-~í //;/"- J. R. Denis, Team Leader PBU New Business Development ) ) BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 EXHIBIT A January 15, 1998 Chevron U. S. A. Inc. Attn: Wade Fennel P. O. Box 1635 Houston, TX 77251-1636 Mobil Alaska E&P Inc Attn: Jeff Hollier 12450 Greenspoint Drive Houston, TX 77060-1991 Notice of Request for Exception to the Provisions of 20 AAC 25.055 NWE 2-01 Gentlemen: Pursuant to the requirements of 20 AAC 25.055 (b), BP Exploration (Alaska) Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25.055 (a) (3). BP Exploration's request, if approved will permit the intersection of the wellbore of the captioned well with the top of the Kuparuk and Ivishak/Sag intervals within 500 feet of the governmental spacing unit in which the well will be bottomed. Specifically, the intersection point applied for will be as follows for the Kuparuk interval: 2233 feet from the south line and 0137 feet from the west line of Section 19, Township 12 North, Range 11 East, Umiat Meridian The intersection point applied for will be as follows for the Ivishak/Sag interval: 2597 feet from the south line and 0761 feet from the west line of Section 20, Township 12 North, Range 11 East, Umiat Meridian ) Mssrs. Fennel and Hollier January 15, 1998 Page 2 ) A copy of the request is attached. Very truly yours, Lp IIJ ;;~ J. R. Denis, Team Leader PBU New Business Development ) ') EXHIBIT B TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF MAILING OF NOTICE Request of BP Exploration (Alaska)) I nc. for an Exception to the ) Provisions of 20 AAC 25.055 ) STATE OF ALASKA ) ) ss. ) THIRD JUDICIAL DISTRICT Rachel Fletcher, being first duly sworn, upon her oath, deposes and says: I am a citizen of the United States of America, over the age of 19 years, and . employed as a secretary for BP Exploration (Alaska), Inc. That on the fifteenth day of January, 1998, I sent true and correct copies of J. R. Denis' January 15, 1998 Notice of Request for Exception to the Provisions of 20 AAC 15.055 via United States Registered Mail, to: Chevron U. S. A. Inc. Attn: Wade Fennel P. O. Box 1635 Houston, TX 77251-1 635 Mobil Alaska E&P Inc. Attn: Jeff Hollier 12450 Greenspoint Drive Houston, TX 77060-1991 I c:::--t--h... DATED at Anchorage, Alaska, this -.-J-dtJån~a. ry, 1J998 j {(2~ ?fA rh Rac el Fletcher I V'-"/ ~ SUBSCRIBED AND SWORN TO before me this J¢day of January 1998. rJ?~ ~ p~ ~à~ry Public, Stat; It ~Ia~ka My Commission Expires: My Con.,ni~ Expires March 12.2000 ~\\\\\\"'I" ""111/& ~ \-eVIE ~ ~ " . ......... G~~ ~ /~..",.. '. ". íJZ ~~"" '..e)' ~ ~ q;... ...;,p ~ ~~" NOTARY \~ ~ = .-J" ".... = ~.\ PUBLIC /.~ ~ ... ..' ~ ~ cP;.··. ....'" ~ ~~..,)."" ..... ....ç,~ ~ ~ 'f OF I\lr ~~ 'lllllIInn "'\\\\\\~ 1/ ,""'" '"\ ' NW EILEEN APPRAISAL WELLS LOCATION MAP ADLt147446 ',".'..' P . ,'.' ' ~ ¡; ~r. 2 w ; liLNWE 2-01* NWE 2~_0 I:E 2-01 " _..>____u... ¡ ," _/__'i':--.~ ".... NW EILEEN APPRAISAL WElLS SURFACE LOCATION WELL X (ASP4/NAD27) NWE 1-02 583276 NWE 1-03 583297 NWE 2-01 570682 ( BOTTOM HOLElTARGET LOCATION WELL X (ASP4/NAD27) ç~~~~~~ == ',' ,', NWE 2-01 571080 NWE 2-01 * 571700 ADL047 .7 ~ ,-- ~ co I, X J.JJ! - () ~12N T11N .,--.._-..-.. ------ r .. ....-,. f~' r- -J .. .. .. . .. . .. .. .~ ....~'t.om ~' ~-~"' .' ~. . ..., I '<:. ,STATE' No.1 r-l., , SOCAL 33-29E , ~ " _. ..J¿y": j',-". ' "'"... . ~ ._~ ~ : ................ ..... -: . ", (j , F t }0 ~ ~-....- - !"""'" Q, N: ~ AD~ ~~ ' " ADL 028~{ , ,}) ; , . WEST SAK 24A ~ (" f \ r' " { ?J -,' ..-,- II '/-? J V R1" "'C ~,- \"~ ~ ~~. \ ~ . '; {":.'"- ".-J----- , . ~ , ~ ~~ .. .- -- -0:-- ~"" o '" .., ;1:: ~ ~ ~ . ~",: , - , . o o ~~, . : ,.. , , NwE ~ ~~DL 028238, :, :'. AO.L 028~40 ,.. - ". . I +- NWE 1-02 ~'" "'. .J.' 1'''10.. """..... -v (.. ItJ . In I , Y (ASP4/NAD27) 5978335 5978356 5986606 '-, Y (ASP4/NAD27) 5980400 5975700 5988390 r 'T12N T1'1~ , . _ ---..... 0 I 1600 I 3000 Feet I BS13719.DGN ) ) EXHIBIT 2 VERIFICATION OF APPLICATION FOR SPACING EXCEPTION NWE 2-01 Floyd Hernandez, Drilling Engineer in the BP Exploration (Alaska) Inc. Shared Service Drilling Department, does hereby verify the following: 1. I am acquainted with the facts associated with the drilling of the NWE 2-01 Well. 2. I have reviewed the application submitted for the exception to 20 AAC 25.055 and all facts therein are true. 3. I have reviewed the plat attached as Exhibit 1 and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this \) day of January, 1998 ~J\ \~ __ Floyd HernandeV STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) SUBSCRIBED AND SWORN TO before me this J 5~ day of January, 1998. \\\\\\\\\ \\, III 111111111 ~\ \'EG~~ ~ ~"''''''''~G ~ ~ ,,~.' "~ ~ ¿§ 41..' ......, ~ ;;§......: .., '.~ ~ gg~: ~þ..R}. ~~~ == 11::: ~O}. =*= šo~ \?Ún.' lC: ~ ~ ",. " ~ .;::: ;:::;: '. .' ~ ~.'. "-~~ ~ ". ,.'tg:" ~ ~ .r'.;...........~~ ~ ~ 'J4TE Of ~ ~ WIIIII"'III\n\\\\\~ Nr!f;;pu¿¿:t!::tSKA My Commission Expires MyCommiseion Expires March 12. 2000 ) ) EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF STUART H. HIRSH Request of BP Exploration (Alaska)) Inc. for an Exception to the ) Provisions of 20 AAC 25.055 ) ) STATE OF ALASKA ) ) ) ss. THIRD JUDICIAL DISTRICT Stuart H. Hirsh, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Stuart H. Hirsh. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Senior Landman for the well operator, BP Exploration (Alaska) Inc. 3. Pursuant to 20 AAC 25.055 (b), BP Exploration (Alaska) Inc. (BPX), the well operator, prepared a Notice of Request for an Exception to the Provision of 20 AAC 25.055. A copy of this notice is attached hereto as Exhibit A. 4. On January 15, 1997, pursuant to 20 AAC 25.055 (b) BPX sent a copy of said notice by registered mail to the last known address of each owner and operator of governmental quarter sections directly and diagonally offsetting the quarter section of the proposed location of the oil well. Attached hereto as Exhibit B is an Affidavit of Mailing of Notice. Subscribed and sworn to this ;' {-í~ day of January, 1998. ,7 ,.J Ap Jt~ sTUART H. HIRSH ) ) STATE OF ALASKA ) ) 55. THIRD JUDICIAL DISTRICT) SUBSCRIBED AND SWORN TO before me this 15~ day of January, 1998. ~~Ubl¿~~ My Commission Expires: '"~\\\\\\\, 11111I1111/111 ~' VIEG % ~ .\-:~""""'~()'~ ~ ".' '. ~ ~ ~~.., ....." ~ ~~.. 0'" '.~ ~ ~cr¡ ~'01'Â.D-l ~....§ -0' ì~ C .*- š..J~ P' , n 1 \ .: ~ ~ tI U u1..-' . ;:: ~ )f:', .' ~ ~ ". ....~ ~ ~ '. " ~ ~ ~ d'/:......... \ ~...~ ~ JtfTE Of ~\. ~ ~1111II"1In\\ \\\\\~ ~ ~'1f,1ission Expires March 12, 2000 H131952 DATE INVOICE I CREDIT MEMO 121797 CK121797H PYMT :OMMENTS: HANDL I NG I NST: -, i -) DESCRIPTION GROSS 100.00 accompany permit to drill application 5th kathy campoanoTJ x5122 E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. /' ~\0\J TOTAL ... ?-·ü\ 100.00 ) VENDOR DISCOUNT DATE 12/19/97 CHECK NO. 00131952 ALASKAST14 NET 00 100.00 100.00 WELL PERMIT CHECKLIST COMPANY ß,/J WELL NAMEPq ,A/aJ,t;' :¿-ð/ PRO~RAM: eX.¥dev 0 redrll 0 serv 0 wellbore seg [: ann. disposal para req Ii FIELD & POOL _~'7~~ c..¡ OJ 6'1ðlÇ, INIT CLASS /..Þ;/ eIr -? --/ GEOL AREA P"9 r") UNIT# I/~~_ ON/OFF SHORE 0 ~__ ADMINISTRATION :f?~~ ENGINEERING ''IF-- i}fð GEOLOGY 3ß! ~,~ 1. Permit fee attached. 2. Lease number appropriate. 3 Unique well name and number. . 4, Well located in a defined pool. . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells. . 7. Sufficient acreage available in drilling unit. . 8, If deviated. is wellbore plat included. 9, Operator only affected party. , 10, Operator has appropriate bond in force. 11, Permit can be issued without conservation order. 12. Permit can be issued without administrative approval, . 13. Can permit be approved before 15-day wait. . (\ y. N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N '\ ~J N 'VN ---- - ...., ~ 2. .-. '-' -3 ~ :::t' - -3 ~ :z -3 - ..... rJ:. rJ:. ( - "" >- t": H REMARKS l _."...,~_,,,,,,,, ,~,_ ....~".. .__~ .-, ,...···..'..·'r..,..._,"..·,.........,,·__.~.,_ ........_"_.._..........._..."".._______""'......._,,____.._~_____' 14 Conductor string provided , . . . . . . .., , ~N 15. Surface casing protects all known USDWs. . .. ",... N 16, CMT vol adequate to circulate on conductor & surf csg. . . .. Y N 17. CMT vol adequate to tie-in long string to surf csg. ..... ~(Ñ\ 18. CMT will cover all known productive horizons. , . . , . M-:( 19, Casing designs adequate for C, T. B & permafrost . N 20, Adequate tankage or reserve pit.. . . . . , . , . . N ",IlL. 21 If a re-drill, has a 10-403 for abandonment been approved., N f'I rr;: 22. Adequate wellbore separation proposed.. . N ~ (j') 1" V" 23, If diverter required, does it meet regulations , N r..J.o' 24, Drilling fiuid program schematic & equip list adequate, N 25. BOPEs. do they meet regulation . . , . ~' N 26, BOPE press rating appropriate; test to ..::::>~.......... psig, N 27, Choke manifold complies w/API RP-53 (May 84) . N 28. Work will occur without operation shutdown. . ,) ~ 29, Is presence of H;:>S gas probable,. , , YC!D --_.. ~------",.. ..,,-_..,u...._........,.......__.' .,_..._____...W_~.,··.'__._...._,._..:_._.."'_.'....._.____,,,....,_......._..._.__.._...____-... 30, 31, 32. 33, 34, Permit can be issued w/o hydrogen sulfide measures, Data presented on potential overpressure zones . Seismic analysis of shallow gas zones. , . I . , , Seabed condition survey (if off-shore). , ~~,.q ~ Contact name/phone for weekly progress reports [exploratory only} WN Y N N Y N ~N .._~':".__.,.,---""_......,._.,._._..._...._....._..__._----_._,_.._..,._-~ ___u._ . . _____ HOW/llt· /, \r:oPt.l\';\",,,,¡,I,", ""J 11'01'1 ---.. GEOLOGY: RP~~ Comments/Instructions·.... I _ _ _ ^.J_ ~ð_1Jt:!i cÞ ~ 2- /J, I· S-frt-oeMc).1 - ~ ~ ~ ~~'-;-- ~ -, -- t::Y ~'-J~¥8~~ ~~. ENGINEERING: COMMIS~' B E\^.l2.a,~ ff eo OW J .Ji)) JDH~ RN~~~ CO ;Y~/q<¡ Cò ) ) 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 simpl.ify 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. . . MICRDFllMED Date 7 / P.,D I f d- ) ) ****************************** * * * * ALASKA COMPUTING CENTER ****************************** *----------------------------* *------- SCHLUMBERGER -------* *----------------------------* ****************************** COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO BP EXPLORATION NWE 2-01 NW EILEEN NORTH SLOPE ALASKA 500292286600 98216 9~ -0·3S- £t gSoz- GA/~o ) LIS Tape Verification Listing Schlumberger Alaska Computing Center ) 27-MAY-1998 16:19 PAGE: 1 REEL HEADER SERVICE NAME EDIT DATE 98/05/27 ORIGIN FLIC REEL NAME 98216 CONTINUATION # PREVIOUS REEL COMMENT B.P. EXPLORATION, NWE 2-01, NW EILEEN, API #50-029-22866-00 **** TAPE HEADER **** SERVICE NAME EDIT DATE 98/05/27 ORIGIN FLIC TAPE NAME 98216 CONTINUATION # 1 PREVIOUS TAPE COMMENT B.P. EXPLORATION, NWE 2-01, NW EILEEN, API #50-029-22866-00 TAPE HEADER NW EILEEN OPEN HOLE WIRELINE LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA RUN 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 98216 S.Morrison T.SIMMONS # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD NWE 2-01 500292286600 BP EXPLORATION SCHLUMBERGER WELL SERVICES 26-MAY-98 RUN 2 RUN 3 19 12N lIE 453 4553 74.00 45.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 12.250 ------------- --------- ---------- 2664.0 13.375 ') ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 2 # 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE DATA ACQUIRED ON BP EXPLORATION WELL NWE 2-01 ON APRIL 2, 1998. TOOLS RUN: PEX/AIT/DSI, PMI, AND CMR. THE PMI AND CMR DATA HAS BEEN DEPTH CORRECTED TO THE AIT GAMMA RAY. THIS DATA IS PRESENTED IN A MODIFIED LDWG FORMAT AS PER DAVE DOUGLAS. THE FORMAT IS: FILE #1: CLIPPED & DEPTH CORRECTED DATA FROM ALL TOOLS @ . 5' SAMPLE RATE. FILE #2: RAW MAIN PASS PEX/AIT/DSI DATA; ALL CURVES @ .1667' SAMPLE RATE. FILE #3: RAW MAIN PASS PMI DATA,· ALL CURVES @ .1667' SAMPLE RATE. FILE #4: RAW MAIN PASS CMR DATA; ALL CURVES @ .1667' SAMPLE RATE. FILE #5: RAW (REPEAT) PEX/AIT/DSI DATA; ALL CURVES @ .1667' SAMPLE RATE. FILE #6: RAW (REPEAT) PMI DATA,· ALL CURVES @ .1667' SAMPLE RATE. NOTE: THERE WAS NO REPEAT PASS LOGGED FOR THE CMR TOOL. $ $ **** FILE HEADER **** FILE NAME EDIT .001 SERVICE FLIC VERSION 001C01 DATE 98/05/27 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 # FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH -------------- AIT CNT SDN DAS FMS CMR $ ----------- ---------- 7457.0 7425.0 7438.0 7378.0 7448.0 5170.0 2658.0 2560.0 2658.0 2658.0 6190.0 2658.0 # BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) ') ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3 BASELINE DEPTH -------------- 88888.0 7305.5 7287.5 7268.0 7257.5 7245.5 7232.5 71 77 .5 7131. 5 7079.0 7076.0 7042.0 7026.0 6992.0 6981.5 6974.0 6955.5 6939.0 6929.5 6915.0 6900.5 6841.5 6824.0 6793.0 6782.0 671 7. 5 6693.5 6680.5 6666.5 6660.0 6617.5 6511.0 6480.5 6475.5 6438.5 6372.5 6308.0 6234.0 6212.5 6192.5 5153.0 5102.0 5048.0 5011 . 0 4869.5 4731. 0 4545.5 4452.0 4447.0 4340.0 4312.5 4272.0 27-MAY-1998 16:19 PAGE: ----------EQUIVALENT UNSHIFTED DEPTH---------- FMS CMR 88889.5 7307.0 7290.5 7270.0 7260.0 7247.0 7234.0 7180.0 7133.5 7081.0 7077.5 7043.5 7027.0 6992.5 6983.5 6975.0 6958.0 6941.5 6931.5 6917.5 6902.5 6844.5 6826.0 6795.0 6784.5 6720.5 6697.0 6682.5 6669.5 6663.0 6620.0 6513.5 6482.5 6478.0 6440.5 6374.5 6309.5 6235.0 6214.0 6195.0 88887.5 5152.5 5101.0 5048.0 5010.5 4868.5 4731.5 4545.5 4452.5 4447.0 4341.0 4312.5 4273.0 ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 4268.5 4231.5 4201.0 4197.0 4182.0 4166.0 4120.5 4118.0 4096.0 4081.0 4059.0 4025.0 3993.0 3965.5 3949.0 3935.5 3906.0 3870.5 3863.5 3858.5 3851.0 3847.0 3838.5 3835.5 3820.0 3807.0 3784.0 3772.5 3757.5 3706.5 3695.0 3604.5 3596.0 3587.5 3568.5 3563.5 3558.5 3547.5 3511. 5 3459.0 3435.0 3412.5 3398.5 3383.5 3357.0 3355.5 3341.0 3293.0 3238.0 3232.5 3228.0 3206.0 3172.5 3162.0 3155.0 4269.0 4232.0 4200.5 4195.5 4183.0 4165.5 4121.5 4118.5 4096.5 4081.0 4059.5 4024.0 3993.5 3966.0 3949.5 3935.5 3906.0 3871. 0 3864.0 3856.0 3849.5 3847.0 3838.0 3835.0 3819.5 3807.5 3783.0 3773.5 3757.5 3706.5 3695.5 3604.5 3596.0 3587.0 3570.0 3564.0 3558.5 3548.5 3511 . 5 3460.0 3435.5 3413.0 3398.5 3383.5 3357.5 3355.5 3340.5 3293.0 3238.0 3233.0 3227.0 3206.0 3172.5 3162.0 3155.0 ) 27-MAY-1998 16:19 PAGE: 4 ) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3153.0 3143.0 3135.5 3122.0 3097.5 3085.5 3073.5 3041.5 3017.0 2913.5 2893.0 2865.5 2845.5 2837.5 2814.0 2795.0 2754.5 2716.5 2693.5 2661.0 2643.0 2636.0 2629.0 2620.5 2574.0 2563.5 100.0 $ 27-MAY-1998 16:19 PAGE: 5 102.5 3152.5 3143.5 3135.5 3122.0 3097.5 3086.0 3073.5 3041.5 3017.5 2913.5 2892.5 2866.0 2845.0 2837.5 2814.0 2795.0 2754.5 2716.5 2693.5 2661.5 2644.5 2635.5 2629. 0 2621.0 2574.5 2563.5 100.0 # MERGED DATA SOURCE LDWG TOOL CODE RUN NO. PASS NO. MERGE TOP MERGE BASE $ -------------- ---------- # REMARKS: # LIS FORMAT DATA -------- --------- THIS FILE CONTAINS THE CLIPPED AND EDITED MAIN PASS AIT/CNT/SDN/DSI, FMS, AND CMR DATA PRESENTED AT 0.5' SAMPLE RATE. THE PRIMARY DEPTH CONTROL FOR THIS WELL IS THE GAMMA RAY FROM THIS AIT TOOL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GR. FMS TO GR. AIT. ALL OTHER FMS CURVES WERE CARRIED WITH THE GR SHIFT,· AND GR. CMR TO GR. AIT. ALL OTHER CMR CURVES WERE CARRIED WITH THE GR SHIFT. THE MAIN PASS DSI DATA HAS BEEN RELABLED AND INCLUDED IN THIS FILE. $ ) ) LIS Tape Verification Listing 27-MAY-1998 16:19 PAGE: 6 Schlumberger Alaska Computing Center * * DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 208 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1092661 00 000 00 0 1 1 1 4 68 0000000000 SP AIT MV 1092661 00 000 00 0 1 1 1 4 68 0000000000 GR AIT GAPI 1092661 00 000 00 0 1 1 1 4 68 0000000000 TENS AIT LB 1092661 00 000 00 0 1 1 1 4 68 0000000000 TEND AIT LB 1092661 00 000 00 0 1 1 1 4 68 0000000000 MRES AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 MTEM AIT DEGF 1092661 00 000 00 0 1 1 1 4 68 0000000000 DEV AIT DEG 1092661 00 000 00 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1092661 00 000 00 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1092661 00 000 00 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1092661 00 000 00 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1092661 00 000 00 0 1 1 1 4 68 0000000000 CRAT CNT 1092661 00 000 00 0 1 1 1 4 68 0000000000 NRAT CNT 1092661 00 000 00 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1092661 00 000 00 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 1092661 00 000 00 0 1 1 1 4 68 0000000000 CALl SDN IN 1092661 00 000 00 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1092661 00 000 00 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1092661 00 000 00 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1092661 00 000 00 0 1 1 1 4 68 0000000000 MSFL SDN OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 MINV SDN OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 MNOR SDN OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 A010 ArT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 A020 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 A030 ArT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 ) ) LIS Tape Verification Listing 27-MAY-1998 16:19 PAGE: 7 Schlumberger Alaska Computing Center --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- A060 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 A090 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 ATI0 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AT20 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AT30 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AT60 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AT90 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AFI0 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AF20 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AF30 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AF60 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 AF90 AIT OHMM 1092661 00 000 00 0 1 1 1 4 68 0000000000 DTCO DAS US/F 1092661 00 000 00 0 1 1 1 4 68 0000000000 DTSM DAS US/F 1092661 00 000 00 0 1 1 1 4 68 0000000000 RSHC DAS 1092661 00 000 00 0 1 1 1 4 68 0000000000 PR DAS 1092661 00 000 00 0 1 1 1 4 68 0000000000 C24 FMS IN 1092661 00 000 00 0 1 1 1 4 68 0000000000 C13 FMS IN 1092661 00 000 00 0 1 1 1 4 68 0000000000 RBI FMS DEG 1092661 00 000 00 0 1 1 1 4 68 0000000000 AZ FMS DEG 1092661 00 000 00 0 1 1 1 4 68 0000000000 CMFF CMR 1092661 00 000 00 0 1 1 1 4 68 0000000000 CMRP CMR PU-S 1092661 00 000 00 0 1 1 1 4 68 0000000000 BFV CMR 1092661 00 000 00 0 1 1 1 4 68 0000000000 KSDR CMR MD 1092661 00 000 00 0 1 1 1 4 68 0000000000 KTIM CMR MD 1092661 00 000 00 0 1 1 1 4 68 0000000000 T2LM CMR 1092661 00 000 00 0 1 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 7457.000 SP.AIT -14.625 GR.AIT -999.250 TENS. AIT 4844.000 TEND.AIT 1695.582 MRES.AIT -999.250 MTEM.AIT -999.250 DEV. AIT -999.250 CNTC.CNT -999.250 CFTC.CNT -999.250 FCNT.CNT -999.250 NCNT. CNT -999.250 CRAT. CNT -999.250 NRAT. CNT -999.250 NPHI.CNT -999.250 CPHI.CNT -999.250 CALI. SDN -999.250 DRHO.SDN -999.250 PEF.SDN -999.250 RHOB.SDN -999.250 MSFL.SDN -999.250 MINV.SDN -999.250 MNOR. SDN -999.250 AOI0 .AIT -999.250 A020 .AIT -999.250 A030.AIT -999.250 A060. AIT -999.250 A090.AIT -999.250 ATI0.AIT -999.250 AT20.AIT -999.250 AT30.AIT -999.250 AT60.AIT -999.250 AT90. AIT -999.250 AFI0.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60. AIT -999.250 AF90.AIT -999.250 DTCO. DAS -999.250 DTSM. DAS -999.250 RSHC. DAS -999.250 PR.DAS -999.250 C24 . FMS -999.250 C13. FMS -999.250 RBl.FMS -999.250 AZ. FMS -999.250 CMFF. CMR -999.250 CMRP. CMR -999.250 BFV. CMR -999.250 KSDR.CMR -999.250 KTIM. CMR -999.250 T2LM.CMR -999.250 DEPT. 2560.000 SP.AIT -999.250 GR. AIT 62.077 TENS.AIT 2596.000 TEND.AIT 1879.514 MRES.AIT 0.107 MTEM. AIT 91. 586 DEV.AIT -999.250 CNTC.CNT 951.793 CFTC.CNT 212.888 FCNT.CNT 214.977 NCNT. CNT 961.049 CRAT. CNT 4.689 NRAT. CNT 5.440 NPHI.CNT 60.778 CPHI.CNT 60.250 CALI. SDN -999.250 DRHO.SDN -999.250 PEF.SDN -999.250 RHOB.SDN -999.250 MSFL.SDN -999.250 MINV. SDN -999.250 MNOR.SDN -999.250 AOI0.AIT -999.250 ) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 8 A020.AIT -999.250 A030.AIT -999.250 A060. AIT -999.250 A090 .AIT -999.250 AT10.AIT -999.250 AT20.AIT -999.250 AT30.AIT -999.250 AT60.AIT -999.250 AT90.AIT -999.250 AF10.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60. AIT -999.250 AF90 . AIT -999.250 DTCO. DAS -999.250 DTSM.DAS -999.250 RSHC. DAS -999.250 PR.DAS -999.250 C24. FMS -999.250 C13 . FMS -999.250 RB1.FMS -999.250 AZ. FMS -999.250 CMFF.CMR -999.250 CMRP.CMR -999.250 BFV.CMR -999.250 KSDR.CMR -999.250 KTIM. CMR -999.250 T2LM. CMR -999.250 END OF DATA **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT . 001 FLIC 001C01 98/05/27 1024 LO **** FILE HEADER **** FILE NAME EDIT . 002 SERVICE FLIC VERSION 001C01 DATE 98/05/27 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX AIT DSI $ 7458.0 7458.0 7458.0 2557.0 2557.0 2557.0 # LOG HEADER DATA ) ) PAGE: 9 27-MAY-1998 16:19 LIS Tape Verification Listing Schlumberger Alaska Computing Center DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AMS PEX AIT $ AUX. MEAS. SONDE PLATFORM EXPRESS ARRAY INDUCTION # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # 03-APR-98 8CO-609 1400 02-APR-98 100 03-APR-98 7476.0 7462.0 2658.0 7452.0 1800.0 TOOL NUMBER ----------- AMS HILTB-FTB AIT-H 12.250 2664.0 2658.0 6%- KCL POLYMER 10.20 54.0 7.5 124.0 0.188 70.0 0.125 70.0 0.225 70.0 THERMAL SANDSTONE 2.65 1.0 Primary depth log Standoffs on AIT & DSI, Bowsprings on CNL. AIT ran in compute standoff and eccentered mode. Maximum deviation: 38.4 deg. PBX (AITH) & DSI ran in combo. DSI ran in P&S, Upper Dipole, lower dipole and BCR modes. THIS FILE CONTAINS THE RAW MAIN PASS PBX/AIT/DSI DATA @ .1667' SAMPLE RATE. REMARKS: ~) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 10 $ # LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPRCODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 208 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1092661 00 000 00 0 2 1 1 4 68 0000000000 SP AIT MV 1092661 00 000 00 0 2 1 1 4 68 0000000000 GR AIT GAPI 1092661 00 000 00 0 2 1 1 4 68 0000000000 TENS AIT LB 1092661 00 000 00 0 2 1 1 4 68 0000000000 HTEN AIT LB 1092661 00 000 00 0 2 1 1 4 68 0000000000 MRES AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 MTEM AIT DEGF 1092661 00 000 00 0 2 1 1 4 68 0000000000 GDEV AIT DEG 1092661 00 000 00 0 2 1 1 4 68 0000000000 CNTC PEX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 CFTC PEX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 RCFT PEX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 RCNT PBX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 TNRA PEX 1092661 00 000 00 0 2 1 1 4 68 0000000000 RTNR PBX 1092661 00 000 00 0 2 1 1 4 68 0000000000 TNPH PBX PU 1092661 00 000 00 0 2 1 1 4 68 0000000000 NPHI PBX PU 1092661 00 000 00 0 2 1 1 4 68 0000000000 NPOR PEX PU 1092661 00 000 00 0 2 1 1 4 68 0000000000 HCAL PEX IN 1092661 00 000 00 0 2 1 1 4 68 0000000000 RHOZ PBX G/C3 1092661 00 000 00 0 2 1 1 4 68 0000000000 ) ) LIS Tape Verification Listing 27-MAY-1998 16:19 PAGE: 11 Schlumberger Alaska Computing Center --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- HDRA PEX G/C3 1092661 00 000 00 0 2 1 1 4 68 0000000000 PEFZ PEX 1092661 00 000 00 0 2 1 1 4 68 0000000000 DPHZ PEX PU 1092661 00 000 00 0 2 1 1 4 68 0000000000 HMIN PEX OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 HMNO PEX OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 RXOZ PEX OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 RX08 PEX OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 HCNT PEX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 HCFT PEX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 HGR PEX GAPI 1092661 00 000 00 0 2 1 1 4 68 0000000000 RHFT PEX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 RHNT PEX CPS 1092661 00 000 00 0 2 1 1 4 68 0000000000 HTNP PEX PU 1092661 00 000 00 0 2 1 1 4 68 0000000000 HNPO PEX PU 1092661 00 000 00 0 2 1 1 4 68 0000000000 A010 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 A020 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 A030 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 A060 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 A090 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AT10 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AT20 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AT30 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AT60 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AT90 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AFI0 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AF20 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AF30 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AF60 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 AF90 AIT OHMM 1092661 00 000 00 0 2 1 1 4 68 0000000000 DTCO DSI US/F 1092661 00 000 00 0 2 1 1 4 68 0000000000 DTSM DSI US/F 1092661 00 000 00 0 2 1 1 4 68 0000000000 RSHC DSI 1092661 00 000 00 0 2 1 1 4 68 0000000000 PR DSI 1092661 00 000 00 0 2 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 7467.000 SP.AIT -999.250 GR.AIT -999.250 TENS. AIT -999.250 HTEN.AIT -999.250 MRES. AIT -999.250 MTEM.AIT -999.250 GDEV. AIT -999.250 CNTC.PEX -999.250 CFTC.PEX -999.250 RCFT.PEX -999.250 RCNT.PEX -999.250 TNRA. PEX -999.250 RTNR. PBX -999.250 TNPH.PBX -999.250 NPHI.PBX -999.250 NPOR.PEX -999.250 HCAL.PEX -999.250 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX -999.250 DPHZ.PEX -999.250 HMIN.PEX -999.250 HMNO. PBX -999.250 RXOZ.PEX -999.250 RX08. PBX -999.250 HCNT.PEX -999.250 HCFT.PBX -999.250 HGR.PEX -999.250 RHFT. PBX -999.250 RENT. PBX -999.250 HTNP.PBX -999.250 HNPO. PBX -999.250 A010 .AIT -999.250 A020.AIT -999.250 A030.AIT -999.250 A060. AIT -999.250 A090. AIT -999.250 AT10.AIT -999.250 AT20.AIT -999.250 AT30.AIT -999.250 AT60.AIT -999.250 AT90.AIT -999.250 AFI0.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60. AIT -999.250 AF90. AIT -999.250 DTCO.DSI -999.250 DTSM.DSI -999.250 RSHC.DSI -999.250 PR.DSI -999.250 ') ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 12 DEPT. 2547.000 SP.AIT -999.250 GR.AIT -999.250 TENS. AIT -999.250 HTEN. AIT -999.250 MRES . AIT -999.250 MTEM.AIT -999.250 GDEV. AIT -999.250 CNTC.PEX -999.250 CFTC.PEX -999.250 RCFT.PEX -999.250 RCNT. PEX -999.250 TNRA.PEX -999.250 RTNR.PEX -999.250 TNPH.PEX -999.250 NPHI.PEX -999.250 NPOR.PEX -999.250 HCAL.PEX -999.250 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX -999.250 DPHZ.PEX -999.250 HMIN. PEX -999.250 HMNO.PEX -999.250 RXOZ.PEX -999.250 RX08.PEX -999.250 HCNT.PEX -999.250 HCFT.PEX -999.250 HGR.PEX -999.250 RHFT.PEX -999.250 RHNT. PEX -999.250 HTNP.PEX -999.250 HNPO.PEX -999.250 A010.AIT -999.250 A020.AIT -999.250 A030.AIT -999.250 A060.AIT -999.250 A090.AIT -999.250 AT10.AIT -999.250 AT20.AIT -999.250 AT30.AIT -999.250 AT60.AIT -999.250 AT90. AIT -999.250 AF10.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60. AIT -999.250 AF90.AIT -999.250 DTCO.DSI -999.250 DTSM. DSI -999.250 RSHC.DSI -999.250 PR.DSI -999.250 END OF DATA ** **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT .002 FLIC 001C01 98/05/27 1024 LO **** FILE HEADER **** FILE NAME EDIT . 003 SERVICE FLIC VERSION 001C01 DATE 98/05/27 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 2 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ) LIS Tape Verification Listing Schlumberger Alaska Computing Center ) 27-MAY-1998 16:19 13 ---------------- ----------- ---------- FMI 7464.0 $ 6183.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- FMI FORM. MICRO. IMAGER $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # REMARKS: PAGE: 03-APR-98 8CO-609 1400 02-APR-98 100 03-APR-98 7476.0 7462.0 2658.0 7452.0 TOOL NUMBER ----------- FBST-B 12.250 2664.0 2658.0 6 % KCL POLYMER 10.20 54.0 7.5 124.0 0.188 70.0 0.125 70.0 0.225 70.0 STANDOFFS ON FMI. THIS FILE CONTAINS THE RAW MAIN PASS FMI DATA @ .1667' SAMPLE RATE. $ # LIS FORMAT DATA ) LIS Tape Verification Listing Schlumberger Alaska Computing Center ) 27-MAY-1998 16:19 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** TYPE ** SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 o 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 o o 32 1 0.166 FT 32 o FT 68 1 1 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1092661 00 000 00 0 3 1 1 4 68 0000000000 GR FMI GAPI 1092661 00 000 00 0 3 1 1 4 68 0000000000 TENS FMI LB 1092661 00 000 00 0 3 1 1 4 68 0000000000 GDEV FMI DEG 1092661 00 000 00 0 3 1 1 4 68 0000000000 C2 FMI IN 1092661 00 000 00 0 3 1 1 4 68 0000000000 Cl FMI IN 1092661 00 000 00 0 3 1 1 4 68 0000000000 RBI FMI DEG 1092661 00 000 00 0 3 1 1 4 68 0000000000 HAZI FMI DEG 1092661 00 000 00 0 3 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- DATA ** DEPT. 7464.000 GR.FMI 75.754 TENS.FMI 1659.000 GDEV.FMI -999.250 C2 . FMI 4.010 Cl . FMI 3.967 RBl.FMI -999.250 HAZI. FMI -999.250 DEPT. 6182.000 GR. FMI -999.250 TENS.FMI -999.250 GDEV. FMI 25.963 C2. FMI -999.250 Cl . FMI -999.250 RBl.FMI 124.163 HAZI.FMI 25.839 END OF DATA ) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 15 FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER EDIT . 003 FLIC 001C01 98/05/27 1024 LO **** FILE HEADER **** FILE NAME EDIT .004 SERVICE FLIC VERSION 001C01 DATE 98/05/27 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 3 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- CMR 5226.0 $ 2548.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 03-APR-98 8CO-609 1400 02-APR-98 100 03-APR-98 7476.0 7462 . 0 2658.0 7452.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- CMR COMB. MAG. RES. IMAGE. $ CMRT ) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 16 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLERS CASING DEPTH (FT): 2664.0 LOGGERS CASING DEPTH (FT): 2658.0 # BOREHOLE CONDITIONS MUD TYPE: 6% KCL POLYMER MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 54.0 MUD PH: 7.5 FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF) : 124.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT) : 0.188 70.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 0.125 70.0 MUD FILTRATE AT (BHT): MUD CAKE AT (MT): 0.225 70.0 MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # REMARKS: Standoffs on AIT, Bowsprings on CMR and CNL. HILT & CMR ran in combo. Bound fluid pass logged only. CMR canceled. Parameters for CMR Bound Fluid. Wait time 0.3s, Number of echos 600, Echo spacing 0.320ms. Echo spacing used should have been 0.2 ms. THIS FILE CONTAINS THE RAW MAIN PASS CMR DATA @ .1667 SAMPLE RATE. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 66 66 73 66 o o 48 1 ') ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 17 ------------------------------ TYPE REPR CODE VALUE ------------------------------ 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM SIZE REPR CODE PROCESS (HEX) --------------------------------------------------------------------------------------- DEPT FT 1092661 00 000 00 0 4 1 1 4 68 0000000000 GR CMR GAPI 1092661 00 000 00 0 4 1 1 4 68 0000000000 TENS CMR LB 1092661 00 000 00 0 4 1 1 4 68 0000000000 HTEN CMR LB 1092661 00 000 00 0 4 1 1 4 68 0000000000 MRES CMR OHMM 1092661 00 000 00 0 4 1 1 4 68 0000000000 MTEM CMR DEGF 1092661 00 000 00 0 4 1 1 4 68 0000000000 CMFF CMR 1092661 00 000 00 0 4 1 1 4 68 0000000000 CMRP CMR PU 1092661 00 000 00 0 4 1 1 4 68 0000000000 BFV CMR 1092661 00 000 00 0 4 1 1 4 68 0000000000 KSDR CMR MD 1092661 00 000 00 0 4 1 1 4 68 0000000000 KTIM CMR MD 1092661 00 000 00 0 4 1 1 4 68 0000000000 T2LM CMR 1092661 00 000 00 0 4 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 5226.000 GR.CMR 129.925 TENS.CMR 3553.000 HTEN. CMR 1634.096 MRES.CMR 0.082 MTEM.CMR 123.874 CMFF.CMR 0.005 CMRP.CMR 0.005 BFV. CMR 0.000 KSDR.CMR 0.000 KTIM. CMR 0.000 T2LM. CMR 64.749 DEPT. 2548.500 GR.CMR 59.975 TENS. CMR 2358.000 HTEN. CMR 1679.335 MRES. CMR 0.087 MTEM.CMR 107.324 CMFF.CMR -999.250 CMRP.CMR -999.250 BFV.CMR -999.250 KSDR.CMR -999.250 KTIM. CMR -999.250 T2LM.CMR -999.250 END OF DATA ') ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 18 **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT . 004 FLIC 001C01 98/05/27 1024 LO **** FILE HEADER **** FILE NAME EDIT . 005 SERVICE FLIC VERSION 001C01 DATE 98/05/27 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 5 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX AIT DSI $ 7464.0 7464.0 7464.0 7133.5 7133.5 7133.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 03-APR-98 8CO-609 1400 02-APR-98 100 03-APR-98 7476.0 7462.0 2658.0 7452.0 1800.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- AMS PEX AUX. MEAS. SONDE PLATFORM EXPRESS AMS HILTB-FTB ) LIS Tape Verification Listing Schlumberger Alaska Computing Center ) 27-MAY-1998 16:19 19 AIT $ ARRAY INDUCTION # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # PAGE: AIT-H 12.250 2664.0 2658.0 6%- KCL POLYMER 10.20 54.0 7.5 124.0 0.188 70.0 0.125 70.0 0.225 70.0 THERMAL SANDSTONE 2.65 1.0 Primary depth log Standoffs on AIT & DSI, Bowsprings on CNL. AIT ran in compute standoff and eccentered mode. Maximum deviation: 38.4 deg. PEX (AITH) & DSI ran in combo. DSI ran in P&S, Upper Dipole, lower dipole and BCR modes. THIS FILE CONTAINS THE RAW REPEAT PEX/AIT/DSI DATA @ .1667' SAMPLE RATE. $ REMARKS: # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 66 66 o o ) ) LI S Tape Verification Listing 27-MAY-1998 16:19 PAGE: 20 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ 3 73 168 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1092661 00 000 00 0 5 1 1 4 68 0000000000 SP AIT MV 1092661 00 000 00 0 5 1 1 4 68 0000000000 GR AIT GAPI 1092661 00 000 00 0 5 1 1 4 68 0000000000 TENS AIT LB 1092661 00 000 00 0 5 1 1 4 68 0000000000 HTEN AIT LB 1092661 00 000 00 0 5 1 1 4 68 0000000000 MRES AIT OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 MTEM AIT DEGF 1092661 00 000 00 0 5 1 1 4 68 0000000000 GDEV AIT DEG 1092661 00 000 00 0 5 1 1 4 68 0000000000 CNTC PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 CFTC PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 RCFT PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 RCNT PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 TNRA PEX 1092661 00 000 00 0 5 1 1 4 68 0000000000 RTNR PEX 1092661 00 000 00 0 5 1 1 4 68 0000000000 TNPH PEX PU 1092661 00 000 00 0 5 1 1 4 68 0000000000 NPHI PEX PU 1092661 00 000 00 0 5 1 1 4 68 0000000000 NPOR PEX PU 1092661 00 000 00 0 5 1 1 4 68 0000000000 HCAL PEX IN 1092661 00 000 00 0 5 1 1 4 68 0000000000 RHOZ PEX G/C3 1092661 00 000 00 0 5 1 1 4 68 0000000000 HDRA PEX G/C3 1092661 00 000 00 0 5 1 1 4 68 0000000000 PEFZ PEX 1092661 00 000 00 0 5 1 1 4 68 0000000000 DPHZ PEX PU 1092661 00 000 00 0 5 1 1 4 68 0000000000 HMIN PEX OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 HMNO PEX OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 RXOZ PEX OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 RX08 PEX OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 HCNT PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 HCFT PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 HGR PEX GAPI 1092661 00 000 00 0 5 1 1 4 68 0000000000 RHFT PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 RHNT PEX CPS 1092661 00 000 00 0 5 1 1 4 68 0000000000 ') ) " LIS Tape Verification Listing 27-MAY-1998 16:19 PAGE: 21 Schlumberger Alaska Compu ting Center --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- HTNP PEX PU 1092661 00 000 00 0 5 1 1 4 68 0000000000 HNPO PEX PU 1092661 00 000 00 0 5 1 1 4 68 0000000000 AF10 AIT OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 AF20 AIT OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 AF30 AIT OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 AF60 AIT OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 AF90 AIT OHMM 1092661 00 000 00 0 5 1 1 4 68 0000000000 DTCO DSI US/F 1092661 00 000 00 0 5 1 1 4 68 0000000000 DTSM DSI US/F 1092661 00 000 00 0 5 1 1 4 68 0000000000 RSHC DSI 1092661 00 000 00 0 5 1 1 4 68 0000000000 PR DSI 1092661 00 000 00 0 5 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 7464.000 SP.AIT -21.875 GR.AIT 187.863 TENS. AIT 4093.000 HTEN. AIT 1284.254 MRES. AIT 0.077 MTEM.AIT 132.733 GDEV. AIT -999.250 CNTC.PEX 1398.394 CFTC.PEX 442.248 RCFT.PEX 405.075 RCNT.PEX 1349.511 TNRA.PEX 3.241 RTNR.PEX 3.483 TNPH.PEX 32.354 NPHI.PEX 33.517 NPOR.PEX 31.526 HCAL.PEX 14.131 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX -999.250 DPHZ.PEX 60721.211 HMIN.PEX 0.381 HMNO.PEX 0.547 RXOZ.PEX 1.504 RX08.PEX 1.498 HCNT. PEX 1398.394 HCFT. PEX 442.248 HGR.PEX 187.863 RHFT.PEX 405.075 RHNT. PEX 1349.511 HTNP.PEX 32.354 HNPO.PEX 31. 526 AF10.AIT 1950.000 AF20.AIT 17.798 AF30.AIT 2.527 AF60.AIT 2.039 AF90.AIT 2.446 DTCO.DSI 107.137 DTSM.DSI 199.087 RSHC.DSI 1.858 PR.DSI 0.296 DEPT. 7133.500 SP.AIT -30.563 GR.AIT 100.888 TENS. AIT 5076.000 HTEN.AIT 2000.213 MRES.AIT 0.075 MTEM.AIT 132.982 GDEV. AIT 15.730 CNTC.PEX 1492.178 CFTC.PEX 507.773 RCFT.PEX 444.940 RCNT.PEX 1483.100 TNRA.PEX 3.064 RTNR.PEX 2.968 TNPH.PEX 29.536 NPHI.PEX 31.256 NPOR.PEX 30.801 HCAL.PEX -999.250 RHOZ.PEX 2.392 HDRA.PEX 0.029 PEFZ.PEX 2.950 DPHZ.PEX 15.639 HMIN.PEX 3.069 HMNO.PEX 2.345 RXOZ.PEX 4.538 RX08.PEX 4.209 HCNT.PEX 1472.450 HCFT.PEX 486.777 HGR.PEX 97.448 RHFT.PEX 418.901 RHNT.PEX 1477.732 HTNP.PEX 30.780 HNPO.PEX 28.287 AF10.AIT 2.937 AF20.AIT 3.077 AF30.AIT 2.859 AF60.AIT 2.693 AF90.AIT 2.638 DTCO.DSI 98.728 DTSM.DSI 174.933 RSHC.DSI 1.772 PR.DSI 0.266 END OF DATA ** ) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-MAY-1998 16:19 PAGE: 22 **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT .005 FLIC 001COl 98/05/27 1024 LO **** FILE HEADER **** FILE NAME EDIT .006 SERVICE FLIC VERSION 001COl DATE 98/05/27 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 6 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 2 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- FMI 7462.0 $ 7275.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 03-APR-98 8CO-609 1400 02-APR-98 100 03-APR-98 7476.0 7462. 0 2658.0 7452.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- FMI FORM. MICRO. IMAGER $ FBST-B # BOREHOLE AND CASING DATA ') LIS Tape Verification Listing Schlumberger Alaska Computing Center ') 27-MAY-1998 16:19 23 OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # REMARKS: PAGE: 12.250 2664.0 2658.0 6% KCL POLYMER 10.20 54.0 7.5 124.0 0.188 70.0 0.125 70.0 0.225 70.0 STANDOFFS ON FMI. THIS FILE CONTAINS THE RAW REPEAT FMI DATA @ .1667' SAMPLE RATE. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 66 66 73 66 66 73 65 68 65 66 68 66 o o o 32 1 0.166 FT 32 .. ) LIS Tape Verification Listing Schlumberger Alaska Computing Center ') 27-MAY-1998 16:19 PAGE: 24 REPR CODE 65 66 66 66 NAME ** SET TYPE - CHAN ** TYPE ------------------------------ VALUE ------------------------------ 14 15 16 o FT 68 1 1 ------------------------------ SERV ID --------------------------------------------------------------------------------------- PROCESS (HEX) UNIT SERVICE API API API API FILE NUMB NUMB ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM SIZE REPR CODE --------------------------------------------------------------------------------------- DEPT FT 1092661 00 000 00 0 6 1 1 4 68 0000000000 GR FMI GAPI 1092661 00 000 00 0 6 1 1 4 68 0000000000 TENS FMI LB 1092661 00 000 00 0 6 1 1 4 68 0000000000 GDEV FMI DEG 1092661 00 000 00 0 6 1 1 4 68 0000000000 C2 FMI IN 1092661 00 000 00 0 6 1 1 4 68 0000000000 C1 FMI IN 1092661 00 000 00 0 6 1 1 4 68 0000000000 RBI FMI DEG 1092661 00 000 00 0 6 1 1 4 68 0000000000 HAZI FMI DEG 1092661 00 000 00 0 6 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. C2 . FMI DEPT. C2 . FMI END OF DATA 7462.000 4.010 7275.000 12.589 GR.FMI C1.FMI GR. FMI C1.FMI **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT .006 FLIC 001C01 98/05/27 1024 LO 87.408 TENS.FMI 1763.000 GDEV. FMI 21. 665 3.967 RB1.FMI 320.638 HAZI. FMI 59.594 84.951 TENS.FMI 3739.000 GDEV. FMI 18.529 12.710 RB1.FMI 338.326 HAZI.FMI 50.208 ) ') '\ LIS Tape Verification Listing Schlumberger Alaska Computing Center 25 27-MAY-1998 16:19 PAGE: **** TAPE TRAILER **** SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENT EDIT 98/05/27 FLIC 98216 1 B.P. EXPLORATION, NWE 2-01, NW EILEEN, API #50-029-22866-00 **** REEL TRAILER **** SERVICE NAME DATE ORIGIN REEL NAME CONTINUATION # PREVIOUS REEL COMMENT EDIT 98/05/27 FLIC 98216 B.P. EXPLORATION, NWE 2-01, NW EILEEN, API #50-029-22866-00 , ), ... ') Sperry-Sun Drilling Services LIS Scan Utility Wed May 27 14:44:39 1998 ) 9~ · o3S- .- --=650? t:t. g,"7 ~_:~ ~/O~/9~ Reel Header Service name............ .LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 98/05/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............. ...UNKNOWN Continuation Number... ...01 Previous Reel Name.... ...UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 98/05/27 Or igin. . . . . . . . . . . . . . . . . . . STS Tape Name......... ...... . UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-80137 B. ZIEMKE R. GENTRY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-80137 A. PIEPER R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MM-80137 A. PIEPER G.W. CRAIG MWD RUN 10 NWE 2-01 500292286600 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 27-MAY-98 MWD RUN 2 AK-MM-80137 B. ZIEMKE R. BORDES MWD RUN 5 AK-MM-80137 A. PIEPER R. BORDES MWD RUN 8 AK-MM-80137 B. ZIEMKE G.W. CRAIG MWD RUN 3 AK-MM-80137 B. ZIEMKE R. BORDES MWD RUN 6 AK-MM-80137 A. PIEPER G.W. CRAIG MWD RUN 9 AK-MM-80137 B. ZIEMKE G.W. CRAIG :» ) ') JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: AK-MM-80137 B. ZIEMKE R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 12N 11E 453 4553 74.10 72.60 43.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 20.000 13.375 9.625 16.000 12.250 8.500 DRILLERS DEPTH (FT) 110.0 2665.0 9281.0 9815.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL LOG DATA/DIGITAL DATA (MERGED CURVES) ARE SHIFTED TO WIRELINE REFERENCE ALL LOG HEADER DEPTHS REMAIN IN DRILLER'S DEPTH REFERENCE. 3. MWD RUNS 1-9 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 10 IS DIRECTIONAL WITH DGR, EWR4, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD RUNS 1-10 REPRESENT NWE 2-01 WITH API#: 50-029-22866-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9815'MD, 9175'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). SBDC SMOOTHED BULK DENSITY COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN NUCLEAR LOG PROCESSING: ... ) ) HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 29000 PPM CHLORIDES MUD WEIGHT: 9.6-9.7 PPG FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name......... ... .STSLIB.OOl Service Sub Level Name... Version Number...... ... ..1.0.0 Date of Generation.. ... ..98/05/27 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.. ... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP FCNT NCNT NPHI PEF DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 76.5 76.5 76.5 76.5 85.0 107.0 108.5 9263.5 9263.5 9263.5 9270.0 9270.0 9270.0 STOP DEPTH 9755.5 9755.5 9755.5 9755.5 9782.5 9755.5 9808.5 9763.0 9763.0 9763.0 9771.5 9771.5 9771.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 76.5 2563.0 2566.5 2617.0 2622.0 2629.5 2633.5 2661.5 2683.5 2688.0 2697.5 2700.5 2703.5 2705.0 2707.5 2711.5 GR 81.0 2567.5 2571.5 2621.0 2624.5 2633.5 2638.0 2663.0 2687.5 2691.5 2700.5 2703.0 2706.5 2708.5 2710.5 2715.5 " 2716.5 2719.0 2794.5 2799.0 2809.5 2812.0 2818.5 2821.5 2822.0 2823.0 2828.5 2829.5 2833.0 2834.5 2835.5 2837.5 2840.5 2842.5 2845.0 2848.5 2871.5 2880.5 2882.5 2886.0 2888.5 2892.0 2905.0 2906.5 2913.0 2917.0 2925.0 2929.5 2936.0 2941.0 2942.5 2944.0 2949.0 2951.0 2956.0 2959.0 2961.5 2966.5 2969.5 2971.5 2975.5 2979.0 2981.5 2995.5 3000.5 3003.0 3005.0 3012.0 3014.0 3071.5 3072.5 3075.5 3076.5 3083.0 3092.0 3097.0 3100.0 '. , ) 2721.0 2722.5 2797.0 2800.0 2813.0 2814.5 2821.0 2823.0 2826.5 2827.0 2832.5 2835.0 2836.0 2838.0 2839.5 2841. 0 2844.5 2847.0 2848.5 2853.5 2873.0 2882.5 2884.5 2889.0 2892.0 2895.0 2908.5 2909.5 2916.0 2920.5 2929.0 2932.5 2940.0 2946.5 2948.0 2949.5 2954.0 2957.0 2960.0 2963.0 2965.0 2970.5 2972.5 2974.5 2979.0 2982.0 2984.5 2997.0 3002.0 3007.0 3009.5 3015.0 3018.0 3075.0 3077.5 3080.5 3081.5 3084.0 3094.5 3100.5 3104.0 3101.5 3108.0 3115.5 3121.5 3123.5 3143.5 3146.0 3148.5 3150.0 3152.5 3155.0 3158.0 3162.0 3166.0 3168.5 3172.5 3192.0 3195.5 3200.5 3205.5 3227.0 3237.5 3241.5 3281.5 3286.5 3290.0 3292.5 3304.5 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3881.5 3884.0 3892.0 3903.5 3905.5 3910.0 3917.0 3920.0 3926.0 3927.0 3928.0 3929.0 3929.5 ) ) 3612.0 3615.0 3619.0 3623.5 3636.0 3638.0 3641.0 3644.0 3651.0 3670.0 3673.0 3675.0 3677.5 3680.0 3687.5 3692.0 3694.0 3695.0 3700.0 3702.0 3703.0 3704.5 3707.5 3711.0 3719.5 3723.5 3727.5 3731.5 3734.5 3745.5 3746.5 3750.0 3751.5 3762.0 3778.0 3786.0 3789.0 3816.0 3822.5 3834.0 3839.5 3841.0 3842.5 3846.0 3851.5 3860.5 3868.5 3875.0 3886.0 3888.5 3896.0 3908.0 3910.0 3914.0 3922.0 3925.0 3930.5 3931.5 3932.0 3932.5 3934.0 3930.5 3937.0 3939.0 3941.0 3943.5 3949.0 3952.5 3966.0 3969.5 3975.5 3978.5 3981.5 3983.0 3984.5 3986.5 3988.5 3990.5 3991.5 3993.0 3993.5 3995.5 3999.5 4002.0 4003.5 4005.5 4007.0 4008.5 4010.5 4012.0 4024.0 4052.0 4053.5 4056.0 4069.5 4075.0 4079.0 4081.0 4082.5 4096.0 4107.5 4109.5 4116.5 4118.0 4122.0 4127.5 4131.0 4132.0 4142.0 4170.0 4182.0 4189.0 4193.0 4195.5 4198.0 4200.5 4207.5 4209.5 4211.0 4212.0 4213.0 4214.0 ) ) 3935.5 3942.0 3943.5 3946.0 3948.0 3954.0 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5925.0 5928.5 5930.0 5932.0 5935.0 5937.5 5941.5 5957.5 5965.5 5969.5 5973.0 5974.5 5978.0 5980.0 5982.5 5987.5 5990.0 5992.0 6002.5 6004.5 6010.5 6014.5 6026.5 6029.5 6033.5 6038.5 6040.0 6042.0 6044.5 6047.5 6052.0 6055.0 6063.0 6066.5 6069.5 6074.0 6076.5 6079.5 6084.5 6087.5 6091.0 6093.0 6100.5 6110.5 6119.0 6125.5 6127.0 6133.5 6136.5 6140.0 6142.5 6157.5 6160.0 6165.0 6166.5 6168.5 ) ) 5919.5 5921.5 5923.0 5927.0 5928.5 5931.0 5934.0 5936.5 5938.0 5941.0 5943.0 5947.5 5964.0 5972.0 5976.5 5980.0 5982.0 5984.5 5986.5 5989.5 5994.5 5995.5 5998.5 6007.5 6011.5 6017.0 6020.0 6032.0 6035.5 6041.0 6044.5 6046.0 6048.5 6052.0 6055.5 6058.5 6062.5 6068.5 6074.0 6077.0 6080.5 6082.0 6086.0 6090.5 6093.0 6098.0 6100.0 6106.5 6113.5 6124.5 6132.0 6134.5 6142.5 6144.0 6146.5 6149.5 6163.0 6167.5 6170.5 6173.0 6174.0 6169.5 6171.0 6176.5 6180.5 6192.0 6234.5 6240.0 6241.5 6243.0 6248.0 6265.5 6270.0 6290.0 6298.5 6300.0 6302.5 6305.0 6313.5 6318.0 6320.5 6329.0 6333.5 6336.0 6337.5 6342.0 6343.5 6345.5 6350.5 6353.0 6355.5 6365.5 6367.0 6368.5 6371.0 6374.0 6377.5 6387.5 6391.0 6393.0 6395.0 6398.5 6399.5 6408.0 6415.0 6421.0 6425.0 6438.0 6440.5 6443.5 6444.5 6450.5 6453.5 6455.5 6456.5 6459.5 6461.5 6463.0 6464.5 6466.0 6476.0 6477.5 ') I ') 6176.0 6178.0 6183.5 6187.0 6199.0 6242.0 6246.5 6249.0 6251.0 6256.5 6271.5 6276.0 6296.5 6305.5 6307.0 6309.5 6312.5 6319.0 6325.5 6327.0 6335.5 6341.0 6342.5 6343.5 6348.0 6350.5 6352.5 6356.5 6359.0 6361.0 6372.0 6373.5 6375.5 6378.0 6381.0 6384.0 6394.0 6397.5 6399.0 6401.0 6405.0 6406.5 6414.5 6422.5 6428.5 6432.0 6444.5 6446.5 6449.0 6451.0 6457.0 6459.5 6461.5 6462.5 6466.0 6467.5 6469.0 6470.5 6472.5 6482.5 6484.0 6480.0 6482.5 6485.0 6486.5 6508.5 6510.5 6513.0 6514.5 6530.5 6532.5 6534.5 6546.0 6549.0 6550.5 6558.0 6578.0 6580.0 6588.5 6590.5 6593.0 6594.5 6606.5 6610.0 6613.0 6616.0 6619.5 6626.5 6629.5 6631.5 6634.5 6647.0 6662.5 6667.0 6669.5 6682.5 6693.5 6706.5 6710.5 6712.0 6714.5 6716.0 6720.0 6721.5 6722.5 6727.5 6729.0 6734.0 6736.5 6739.0 6740.5 6745.0 6755.5 6761.0 6762.5 6765.5 6782.0 6784.0 6786.0 6788.0 6789.5 6792.5 ) ') 6486.5 6489.0 6491.5 6493.0 6515.0 6517.5 6519.5 6521.5 6537.5 6539.0 6541.0 6553.0 6556.0 6557.0 6565.0 6585.0 6586.0 6594.0 6597.0 6599.5 6601.5 6610.5 6617.0 6620.0 6622.5 6626.0 6633.0 6635.5 6638.0 6641.5 6654.5 6669.0 6674.0 6676.0 6689.5 6700.0 6712.5 6717.5 6719.0 6722.0 6723.0 6726.5 6728.0 6729.0 6733.5 6735.0 6740.5 6743.5 6746.5 6748.0 6750.5 6764 .0 6767.5 6770.0 6771.5 6788.5 6790.0 6792.5 6794.0 6798. 0 6799.5 ) ) 6795.0 6801. 0 6798.0 6803.5 6809.0 6816.5 6842.0 6850.5 6844.0 6851.5 6888.5 6896.5 6895.0 6902.0 6902.5 6910.5 6904.5 6912.5 6917.5 6925.0 6921.0 6928.5 6925.0 6931.0 6931.0 6939.0 6933.5 6941.5 6938.0 6945.5 6941.0 6948.0 6944.5 6952.0 6951.0 6958.0 6957.5 6965.5 6960.0 6968.5 6967.0 6972.5 6975.0 6982.0 6979.5 6985.0 6982.5 6990.5 6986.5 6994.5 6989.0 6996.5 6992.5 7001. 0 6997.5 7005.0 7001.0 7007.0 7014.5 7021. 5 7026.5 7034.5 7029.5 7037.0 7034.0 7041.5 7038.5 7045.5 7041.5 7047.5 7043.0 7050.0 7046.0 7052.0 7067.0 7074.0 7069.0 7076.5 7081.0 7087.5 7094.0 7101.5 7115.0 7121.0 7127.0 7132.0 7129.5 7137.0 7133.0 7140.0 7136.0 7143.0 7142.0 7147.0 7143.5 7149.0 7146.5 7152.0 7153.0 7160.5 7155.0 7162.0 7166.5 7173.0 7169.0 7175.0 7179.5 7186.5 7181.5 7188.5 7183.5 7191.0 7186.0 7194.0 7194.5 7202.0 7199.0 7207.5 7211.5 7219.0 7214.0 7221.5 7222.0 7227.0 7233.0 7244.5 7246.5 7248.0 7249.5 7257.5 7259.5 7261.5 7265.0 7266.5 7268.0 7269.5 7360.0 7363.0 7376.0 7385.5 7388.0 7396.5 7398.0 7401.0 9808.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: ) 7229.0 7234.0 7240.5 7250.0 7253.5 7255.0 7256.5 7264.0 7265.5 7268.0 7271.5 7273.5 7274.5 7276.5 7366.5 7370.0 7382.5 7392.0 7395.5 7403.0 7404.5 7407.5 9815.0 BIT RUN NO 1 2 3 4 5 6 7 8 9 10 MERGED MAIN PASS. $ MERGE TOP 110.0 2680.0 5939.0 6847.0 7035.0 7476.0 7484.0 8375.0 8860.0 9280.0 ) MERGE BASE 2680.0 5939.0 6847.0 7035.0 7476.0 7484.0 8375.0 8860.0 9280.0 9815.0 # Data Format Specification Record Data Record Type.... ... ....... ....0 Data Specification Block Type. ....0 Logging Direction.............. ...Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.......... ...... .... .60 .1IN Max frames per record......... ....Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT\H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 ') ) RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD P.U. 4 1 68 32 9 NCNT MWD CNTS 4 1 68 36 10 FCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CC 4 1 68 44 12 DRHO MWD G/CC 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 76.5 9808.5 4942.5 19465 76.5 9808.5 ROP 3.3842 4090.43 110.672 19374 108.5 9808.5 GR 12.0403 547.441 81.178 19396 85 9782..5 RPX 0.0878 2000 7.52937 19289 76.5 9755.5 RPS 0.1876 2000 12.4862 19289 76.5 9755.5 RPM 0.2263 2000 25.1556 19289 76.5 9755.5 RPD 0.2659 2000 31.9754 19289 76.5 9755.5 FET 0.1629 167.448 3.65613 19228 107 9755.5 NPHI 6.7064 81.7622 29.8157 1000 9263.5 9763 NCNT 2224 4672.4 3283.2 1000 9263.5 9763 FCNT 416 1911.83 862.594 1000 9263.5 9763 RHOB 1.231 2.7474 2.4876 1004 9270 9771.5 DRHO -0.092 0.3189 0.0196521 1004 9270 9771.5 PEF 0.1132 4.2594 1.44272 1004 9270 9771.5 First Reading For Entire File......... .76.5 Last Reading For Entire File..... ..... .9808.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 ') DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD GR FET ROP $ .5000 START DEPTH 81.0 81.0 81.0 81.0 89.5 111.5 113.0 STOP DEPTH 2651.0 2651.0 2651.0 2651.0 2658.5 2651.0 2680.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # ) 13-MAR-98 5.07 5.46 MEMORY 2680.0 110.0 2680.0 .0 .6 TOOL NUMBER P0971CRG8 P0971CRG8 16.000 16.0 SPUD 10.60 80.0 9.4 300 14.0 6.000 5.600 4.500 9.000 28.9 ') ) Data Format Specification Record Data Record Type........ ........ ..0 Data Specification Block Type... ..0 Logging Direction.............. ...Down Optical log depth units........ ...Feet Data Reference Point........... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 RPX MWD 1 OHMM 4 1 68 12 4 RPS MWD 1 OHMM 4 1 68 16 5 RPM MWD 1 OHMM 4 1 68 20 6 RPD MWD 1 OHMM 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 81 2680 1380.5 5199 81 2680 ROP 4.6897 1575.08 148.616 5108 113 2680 GR 12.0403 81.4521 45.1555 5139 89.5 2658.5 RPX 0.656 55.9318 22.0796 5141 81 2651 RPS 0.5616 116.519 35.9997 5141 81 2651 RPM O. 4626 2000 72.2366 5141 81 2651 RPD 0.2659 2000 94.1389 5141 81 2651 FET 0.1629 8.5331 0.772749 5080 111. 5 2651 First Reading For Entire File........ ..81 Last Reading For Entire File......... ..2680 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record. .65535 File Type................ LO Next File Name.... ...... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..98/05/27 Maximum Physical Record..65535 File Type..... ... .... ....LO Previous File Name.. ... ..STSL1B.002 ) Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 2651.5 2651.5 2651.5 2651.5 2651.5 2659.0 2680.5 STOP DEPTH 5893.0 5893.0 5893.0 5893.0 5893.0 5900.5 5939.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 21-MAR-98 5.07 5.46 MEMORY 5939.0 2680.0 5939.0 .2 38.4 TOOL NUMBER P0971CRG8 P0971CRG8 12.250 12.3 KCL/POLYMER 9.60 42.0 8.2 23000 6.2 .230 .146 54.4 .120 .300 ') ) # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ............ ....0 Data Specification Block Type.. ...0 Logging Direction...... .......... . Down Optical log depth units.......... .Feet Data Reference Point. ........ .... . Undefined Frame Spacing........ ............ .60 .1IN Max frames per record.......... ...Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 2651.5 5939.5 4295.5 6577 2651.5 5939.5 ROP 8.7709 4090.43 169.247 6519 2680.5 5939.5 GR 13.933 199.692 80.3247 6484 2659 5900.5 RPX 0.1059 7.0114 2.16565 6484 2651.5 5893 RPS 0.1717 2000 5.26594 6484 2651.5 5893 RPM 0.2352 2000 13.5812 6484 2651.5 5893 RPD 0.4026 2000 14.2143 6484 2651.5 5893 FET 0.2142 118.223 2.28067 6484 2651.5 5893 First Reading For Entire File... ... ... .2651.5 Last Reading For Entire File..... ..... .5939.5 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...98/05/27 Maximum Physical Record..65535 F i 1 e Type................ LO Next File Name. ........ ..STSLIB.004 Physical EOF File Header ) Service name... ......... .STSLIB.004 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 ') header data for each bit run in separate files. 3 .5000 START DEPTH 5893.5 5893.5 5893.5 5893.5 5893.5 5901.5 5940.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 6801.0 6801.0 6801.0 6801.0 6801.0 6809.0 6847.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 24-MAR-98 5.07 5.46 MEMORY 6847.0 5939.0 6847.0 16.7 33.1 TOOL NUMBER P0966CRG8 P0966CRG8 12.250 12.3 KCL/POLYMER 10.20 53.0 8.3 30000 6.4 .240 .148 57.8 ') ) MUD FILTRATE AT MT: MUD CAKE AT MT: .160 .260 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ..... ....0 Data Specification Block Type.....O Logging Direction............ .....Down Optical log depth units.......... .Feet Data Reference Point... ....... ... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 RPX MWD 3 OHMM 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 OHMM 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 5893.5 6847.5 6370.5 1909 5893.5 6847.5 ROP 7.8691 600.586 38.9276 1816 5940 6847.5 GR 69.7227 317.528 144.114 1816 5901.5 6809 RPX 0.5356 5.0182 1.23903 1816 5893.5 6801 RPS 0.7085 14.1853 1.8723 1816 5893.5 6801 RPM 0.7525 12.775 2.13617 1816 5893.5 6801 RPD 0.8045 9.1793 2.24432 1816 5893.5 6801 FET 1.1449 21.6166 2.82925 1816 5893.5 6801 First Reading For Entire File. ...... ...5893.5 Last Reading For Entire File... ..... ...6847.5 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..98/05/27 Maximum Physical Record..65535 File Type....... ........ .LO ) Next File Name... ...... ..STSLIB.005 Physical EOF File Header Service name..... ...... ..STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...98/05/27 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 5 ) header data for each bit run in separate files. 4 .5000 START DEPTH 6801.5 6801.5 6801.5 6801.5 6801.5 6809.5 6848.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 7024.0 7024.0 7024.0 7024.0 7024.0 7031.5 7034.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 26-MAR-98 5.07 5.46 MEMORY 7035.0 6847.0 7035.0 14.9 16.9 TOOL NUMBER P0966CRG8 P0966CRG8 12.250 12.3 KCL/POLYMER 10.20 ') MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type.....O Logging Direction.. ... .......... ..Down Optical log depth units..... ... ...Feet Data Reference Point.. .... ..... ...Undefined Frame Spacing.... ............... ..60 .1IN Max frames per record.. ..... ..... . Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type...O ') 53.0 8.0 31000 7.0 .220 .137 .150 .260 58.3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 RPX MWD 4 OHMM 4 1 68 12 4 RPS MWD 4 OHMM 4 1 68 16 5 RPM MWD 4 OHMM 4 1 68 20 6 RPD MWD 4 OHMM 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Min 6801.5 5.2489 70.0929 0.2377 0.451 0.5009 0.6247 0.2906 Mean 6918 25.2878 110.113 1.02197 1.60494 1.91013 2.04759 8.49309 Nsam 467 374 445 446 446 446 446 446 Max 7034.5 143.881 139.172 2.448 4.9005 5.5698 5.1238 38.6608 First Reading For Entire File. .... .... .6801.5 Last Reading For Entire File.... ...... .7034.5 First Reading 6801.5 6848 6809.5 6801.5 6801.5 6801.5 6801.5 6801.5 Last Reading 7034.5 7034.5 7031.5 7024 7024 7024 7024 7024 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ ') File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...98/05/27 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name........... ..STSLIB.006 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.... ...98/05/27 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 6 .5000 START DEPTH 7024.5 7024.5 7024.5 7024.5 7032.0 7035.0 7036.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 7430.0 7430.0 7430.0 7430.0 7437.5 7430.0 7476.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # ) 29-MAR-98 5.07 5.46 MEMORY 7476.0 7035.0 7476.0 14.8 18.9 TOOL NUMBER P0966CRG8 P0966CRG8 ) BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........... ..... ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type...O ) 12.250 12.3 KCL/POLYMER 10.20 44.0 8.1 32000 4.4 .230 .153 56.1 .170 .280 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 RPX MWD 5 OHMM 4 1 68 12 4 RPS MWD 5 OHMM 4 1 68 16 5 RPM MWD 5 OHMM 4 1 68 20 6 RPD MWD 5 OHMM 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 7024.5 7476.5 7250.5 905 7024.5 7476.5 ROP 7.4025 120.82 36.6701 882 7036 7476.5 GR 36.5656 110.477 82.3225 812 7032 7437.5 RPX 0.7039 2.5808 1.4003 812 7024.5 7430 RPS 1.1089 7.6083 2.73229 812 7024.5 7430 RPM 1.2504 10.8169 3.32603 812 7024.5 7430 RPD 1.3044 10.5257 3.60156 812 7024.5 7430 ) FET 1.3104 7.31927 48.9942 791 First Reading For Entire File... ...... .7024.5 Last Reading For Entire File... ....... .7476.5 File Trailer Service name. ..... ...... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record. .65535 File Type................ LO Next File Name..... ... ...STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 7 ) 7035 7430 header data for each bit run in separate files. 6 .5000 START DEPTH 7431.5 7431.5 7431.5 7431.5 7431.5 7439.0 7479.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7437.5 7437.5 7437.5 7437.5 7437.5 7445.0 7484.0 04-APR-98 5.07 5.46 MEMORY 7484.0 7476.0 7484.0 14.8 18.9 ) # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point........... ...Undefined Frame Spacing............. ....... .60 .1IN Max frames per record... ......... . Undefined Absent value......... ....... ......-999.25 Depth Units....................... Datum Specification Block sub-type...O ) TOOL NUMBER P0966CRG8 P0966CRG8 12.250 12.3 KCL/POLYMER 10.30 60.0 8.9 30000 3.8 .240 .180 38.4 .170 .300 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 68 4 2 GR MWD 6 API 4 1 68 8 3 RPX MWD 6 OHMM 4 1 68 12 4 RPS MWD 6 OHMM 4 1 68 16 5 RPM MWD 6 OHMM 4 1 68 20 6 RPD MWD 6 OHMM 4 1 68 24 7 FET MWD 6 HOUR 4 1 68 28 8 Name Min Max Mean Nsam First Reading Last Reading ) ) DEPT 7431.5 7484 7457.75 106 7431.5 7484 ROP 6.8563 36.5771 17.296 11 7479 7484 GR 85.193 94.9874 89.5115 13 7439 7445 RPX 0.7053 1.3389 0.976954 13 7431.5 7437.5 RPS 1.4055 2.1761 1.75678 13 7431.5 7437.5 RPM 1.893 2.8412 2.28034 13 7431.5 7437.5 RPD 2.2144 3.0212 2.52082 13 7431.5 7437.5 FET 135.782 137.723 136.769 13 7431.5 7437.5 First Reading For Entire File... ...... .7431.5 Last Reading For Entire File........ ...7484 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation.... ...98/05/27 Maximum Physical Record. .65535 File Type................ LO Next File Name......... ..STSLIB.008 Physical EOF File Header Service name........... ..STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..98/05/27 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name.... ...STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 8 header data for each bit run in separate files. 7 .5000 START DEPTH 7438.0 7438.0 7438.0 7438.0 7438.0 7445.5 7484.5 STOP DEPTH 8330.0 8330.0 8330.0 8330.0 8330.0 8338.0 8376.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 07-APR-98 5.07 5.46 MEMORY ) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record D a taR e cor d T yp e. . . . . . . . . . . . . . . . . . 0 Data Specification Block Type.. ...0 Logging Direction........... ..... . Down Optical log depth units........ ...Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value..................... .-999.25 Depth Units....................... Datum Specification Block sub-type...O ') 8375.0 7484.0 8375.0 21.6 28.2 TOOL NUMBER P0966CRG8 P0966CRG8 12.250 12.3 KCL/POLYMER 10.20 70.0 8.8 29000 4.9 .240 .142 61.7 .160 .260 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 7 FT/H 4 1 68 4 2 GR MWD 7 API 4 1 68 8 3 RPX MWD 7 OHMM 4 1 68 12 4 RPS MWD 7 OHMM 4 1 68 16 5 RPM MWD 7 OHMM 4 1 68 20 6 I 4 ~ I ) RPD MWD 7 FET MWD 7 OHMM HOUR 4 4 ) 1 68 1 68 24 28 7 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 7438 8376.5 7907.25 1878 7438 8376.5 ROP 3.7354 156.522 39.8412 1785 7484.5 8376.5 GR 60.612 125.169 94.9877 1786 7445.5 8338 RPX 0.3152 2.132 1.15324 1785 7438 8330 RPS 0.7264 4.6026 1.78225 1785 7438 8330 RPM 0.9662 5.4162 2.06024 1785 7438 8330 RPD 1. 0053 5.141 2.1906 1785 7438 8330 FET 1.0435 167.448 9.17069 1785 7438 8330 First Reading For Entire File... ...... .7438 Last Reading For Entire File..... ..... .8376.5 File Trailer Service name........... ..STSLIB.008 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name...... ...... .STSLIB.009 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation. ..... .98/05/27 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 9 header data for each bit run in separate files. 8 .5000 START DEPTH 8330.5 8330.5 8330.5 8330.5 8330.5 8338.5 8377.0 STOP DEPTH 8813.0 8813.0 8813.0 8813.0 8813.0 8820.5 8859.5 " ) # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ...... ..... ..0 Data Specification Block Type.....O Logging Direction....... .... ..... . Down Optical log depth units...... .....Feet Data Reference Point..... ....... ..Undefined Frame Spacing..... .... ...... ..... .60 .1IN Max frames per record.... ... ......Undefined Absent value...................... -999.25 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 09-APR-98 5.07 5.46 MEMORY 8860.0 8375.0 8860.0 16.5 25.5 TOOL NUMBER P0966CRG8 P0966CRG8 12.250 12.3 KCL/POLYMER 10.20 63.0 8.5 29000 5.6 .230 .139 63.9 .170 .280 ) ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 8 FT/H 4 1 68 4 2 GR MWD 8 API 4 1 68 8 3 RPX MWD 8 OHMM 4 1 68 12 4 RPS MWD 8 OHMM 4 1 68 16 5 RPM MWD 8 OHMM 4 1 68 20 6 RPD MWD 8 OHMM 4 1 68 24 7 FET MWD 8 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 8330.5 8859.5 8595 1059 8330.5 8859.5 ROP 8.3214 213.281 32.5967 966 8377 8859.5 GR 67.7037 128 95.1622 965 8338.5 8820.5 RPX 0.5602 1.7677 1.08056 966 8330.5 8813 RPS 0.9139 3.455 1. 69021 966 8330.5 8813 RPM 0.9785 3.9711 1.9124 966 8330.5 8813 RPD 1.0306 3.5348 2.00403 966 8330.5 8813 FET 1. 1239 31.5505 5.28159 966 8330.5 8813 First Reading For Entire File.... ..... .8330.5 Last Reading For Entire File..... ......8859.5 File Trailer Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.010 Physical EOF File Header Service name............ .STSLIB.010 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.. .... .98/05/27 Maximum Physical Record..65535 File Type............ ....LO Previous File Name..... ..STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET 10 header data for each bit run in separate files. 9 .5000 START DEPTH 8814.0 STOP DEPTH 9234.5 ,I ) RPD RPM RPS RPX GR ROP $ 8814.0 8814.0 8814.0 8814.0 8821.5 8861.5 9234.5 9234.5 9234.5 9234.5 9242.0 9280.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... .... .... ......0 Data Specification Block Type. ....0 Logging Direction... ............. . Down Optical log depth units... ....... .Feet ) 11-APR-98 5.07 5.46 MEMORY 9280.0 8860.0 9280.0 8.1 14.5 TOOL NUMBER P0966CRG8 P0966CRG8 12.250 12.3 KCL/POLYMER 10.30 48.0 9.1 30000 4.2 .240 .140 65.6 .170 .300 " " ") ) Data Reference Point.......... ....Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value..................... .-999.25 Depth Units....................... Datum Specification Block sub-type. ..0 Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR Size 4 4 4 4 4 4 4 4 Nsam Rep 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 Code Offset o 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 Name DEPT ROP GR RPX RPS RPM RPD FET MWD 9 MWD 9 MWD 9 MWD 9 MWD 9 MWD 9 MWD 9 First Last Name Min Max Mean Nsam Reading Reading DEPT 8814 9280.5 9047.25 934 8814 9280.5 ROP 3.3842 86.7876 30.2354 839 8861.5 9280.5 GR 75.5864 147.999 104.19 842 8821.5 9242 RPX 0.5391 2.0629 1.12588 842 8814 9234.5 RPS 0.8058 3.9917 1.66982 842 8814 9234.5 RPM 0.8539 4.3959 1.83456 842 8814 9234.5 RPD 0.9084 4.6392 1.91871 842 8814 9234.5 FET 1.4358 32.4424 5.50858 842 8814 9234.5 First Reading For Entire File..... .... .8814 Last Reading For Entire File......... ..9280.5 File Trailer Service name............ .STSLIB.010 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record. .65535 File Type..... ...... .... .LO Next File Name.......... .STSLIB.011 Physical EOF File Header Service name...... .... ...STSLIB.011 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .98/05/27 Maximum Physical Record. .65535 F i leT ype. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD ,I ) Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB ROP $ ) header data for each bit run in separate files. 10 .5000 START DEPTH 9242.5 9270.0 9270.0 9270.0 9270.0 9270.0 9270.0 9270.0 9270.0 9276.5 9276.5 9276.5 9281.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9789.0 9769.5 9769.5 9769.5 9762.0 9762.0 9762.0 9762.0 9762.0 9778.0 9778.0 9778.0 9815.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 18-APR-98 5.07 5.46 MEMORY 9815.0 9280.0 9815.0 5.4 8.7 TOOL NUMBER P0972CRNLG6 P0972CRNLG6 P0972CRNLG6 P0972CRNLG6 8.500 8.5 KCL/POLYMER 9.70 48.0 9.0 29000 2.8 .230 .130 65.6 .120 .300 oIJ )' · ) ) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ..... ...0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units........ ...Feet Data Reference Point............ ..Undefined Frame Spacing............. .... ... .60 .1IN Max frames per record............ . Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 10 FT/H 4 1 68 4 2 GR MWD 10 API 4 1 68 8 3 RPX MWD 10 OHMM 4 1 68 12 4 RPS MWD 10 OHMM 4 1 68 16 5 RPM MWD 10 OHMM 4 1 68 20 6 RPD MWD 10 OHMM 4 1 68 24 7 FET MWD 10 HOUR 4 1 68 28 8 NPHI MWD 10 P.U. 4 1 68 32 9 FCNT MWD 10 CNTS 4 1 68 36 10 NCNT MWD 10 CNTS 4 1 68 40 11 RHOB MWD 10 G/CC 4 1 68 44 12 DRHO MWD 10 G/CC 4 1 68 48 13 PEF MWD 10 BARN 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 9242.5 9815 9528.75 1146 9242.5 9815 ROP 4.435 181.222 32.3477 1069 9281 9815 GR 24.517 547.441 86.7956 1094 9242.5 9789 RPX 0.0878 2000 9.93051 985 9270 9762 RPS 0.1876 101.41 9.03664 985 9270 9762 RPM 0.2263 2000 11.266 985 9270 9762 RPD 0.351 2000 23.2797 985 9270 9762 FET 1.3109 151.136 13.2351 985 9270 9762 NPHI 6.7064 81.7622 29.8157 1000 9270 9769.5 FCNT 416 1911.83 862.594 1000 9270 9769.5 NCNT 2224 4672.4 3283.2 1000 9270 9769.5 RHOB 1.231 2.7474 2.4876 1004 9276.5 9778 DRHO -0.092 0.3189 0.0196521 1004 9276.5 9778 PEF 0.1132 4.2594 1.44272 1004 9276.5 9778 First Reading For Entire File......... .9242.5 Last Reading For Entire File..... .... ..9815 ~'1 \tI..' .. ') ) File Trailer Service name.......... ...STSLIB.011 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation..... ..98/05/27 Maximum Physical Record. .65535 F i 1 e Type................ LO Next File Name....... ... .STSLIB.012 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 98/05/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 98/05/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name......... ..... ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File