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Home My WebLink About196-1117. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU B-02A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 196-111 50-029-20066-01-00 12283 Circulation Intermediate Intermediate Liner Liner 9075 2171 4526 5673 4920 2116 746 16" 13-3/8" 9-5/8" x 10-3/4" x 9-5/8" 7" 4-1/2" 746 30 - 2201 28 - 4554 26 - 5663 5465 - 10385 10167 - 12283 30 - 2201 28 - 4331 26 - 5196 5042 - 8613 8458 - 9075 746, 1101, 1224 1540 / 1950 4760 / 3390 / 4760 7020 7500 10124 3090 / 3450 6870 / 4430 / 6870 8160 8430 10400 - 12165 4-1/2" 12.6# L80 24 - 636 / 1200 - 10171 8624 - 9035 Surface 2284 20" 32 - 2316 32 - 2316 2320 / 1530 1500 / 520 4-1/2" Baker S-3 Hydro Set Packer 10115 8420 Torin Roschinger Operations Manager Andrew Ogg andrew.ogg@hilcorp.com 907.659.5102 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028310 24 - 636 / 1200 - 8460 N/A N/A Suspended N/A 13b. Pools active after work:PRUDHOE OIL 10115, 8420 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:16 am, Aug 20, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.20 06:54:59 - 08'00' Torin Roschinger (4662) WCB 10-2-2024 RBDMS JSB 082824 ACTIVITY DATE SUMMARY 7/22/2024 T/I/O = 350/375/175/100/75. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Austin McLeod. Pictures taken. SV, MV = C. IA , OA, OOA, OOOA = OTG. 12:00. Daily Report of Well Operations PBU B-02A B-02A 4-1/2" HES “XN” NIP, ID = 3.725" 4-1/2" 12.6# L-80 NSCT Workstring6636' 625' Top of Underreamed CMT 12/03/18746'CTM 800'HES ‘Fasdrill’ Bridge Plug 1720' 1415' Jet Cut, 4-1/2" Tubing Jet Cut, 4-1/2" Tubing Chemical Cut, 4-1/2" Tubing HES 4-1/2" ‘Fasdrill’ Bridge Plug 10048' NOTE :WELL WAS L EFT W/9.8 NaCl BRINE IN ANNULUS AND 20BBLS DIESEL F/P. 10124' SUSPENDED Reviewed By: P.I. Suprv Comm ________ :ZϬϴͬϯϬͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐ^DϮϰϬϳϮϮϭϴϮϳϬϭ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϳͬϮϮͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƵƐƚŝŶDĐ>ĞŽĚ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϯͬϭͬϮϬϭϬ η ϯϭϬͲϬϮϳ dƵďŝŶŐ͗ϯϱϬ /͗ϯϳϱ K͗ϭϳϱ KƉĞƌĂƚŽƌ͗,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ͕>> KƉĞƌĂƚŽƌZĞƉ͗ŶĚƌĞǁKŐŐ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϳͬϭϲͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ tĞůůEĂŵĞ͗WZh,KzhE/dͲϬϮ WĞƌŵŝƚEƵŵďĞƌ͗ϭϵϲϭϭϭϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ ƌǇŚŽůĞƚƌĞĞͲEŽ^^s͘dǇƉŝĐĂůĐŚŝƉƉĞĚƉĂŝŶƚ͘tĞƚĨƌŽŵƌŽŽĨŽĨǁĞůůŚŽƵƐĞůĞĂŬŝŶŐ͘EŽůĞĂŬƐĨƌŽŵǁĞůů͘ůůǀĂůǀĞƐŽƉĞƌĂďůĞ͘ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ ůĞĂŶƉĂĚŐƌĂǀĞů͘ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ ^ŽŵĞƌĂŝŶǁĂƚĞƌͲŶŽǀŝƐŝďůĞƐŚĞĞŶ͘,ĂƌĚƌĂŝŶĨŽƌϭϴͲϮϰŚƌƐƉƌŝŽƌƚŽŝŶƐƉĞĐƚŝŽŶ͘ ŽŵŵĞŶƚƐ KKͲϭϬϬƉƐŝ͖KKKͲϳϱƉƐŝ͘WĂĚŵĂƉƵƐĞĚ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ EŽŝƐƐƵĞƐ͖WŚŽƚŽƐ;ϭϬͿĂƚƚĂĐŚĞĚ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌǇ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ &ƌŝĚĂǇ͕ƵŐƵƐƚϯϬ͕ϮϬϮϰ 9 9 99 9 9 9 9 9 9 2024-0722_Suspend_PBU_B-02A_photos_am Page 1 of 5 Suspended Well Inspection – PBU B-02A PTD 1961110 AOGCC Inspection # susSAM240722182701 Photos by AOGCC Inspector A. McLeod 7/22/2024 2024-0722_Suspend_PBU_B-02A_photos_am Page 2 of 5 2024-0722_Suspend_PBU_B-02A_photos_am Page 3 of 5 2024-0722_Suspend_PBU_B-02A_photos_am Page 4 of 5 Tubing pressure IA and OA pressures 2024-0722_Suspend_PBU_B-02A_photos_am Page 5 of 5 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:196-111 6.50-029-20066-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12283 725 725 10115 1101, 1224 725, 800, 10124 84 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 30" 32 - 112 32 - 112 Surface 2053 20" 32 - 2316 32 - 2316 2320 / 1530 1500 / 520 Intermediate 2171 16" 30 - 2201 30 - 2201 Intermediate 4526 13-3/8" 28 - 4554 28 - 4331 3090 / 3450 1540 / 1950 Intermediate 5637 9-5/8" x 10-3/4" x 926 - 5663 26 - 5196 6870 / 4430 / 6870 4760 / 3390 / 4760 Perforation Depth: Measured depth: 10400 - 12165 feet True vertical depth:8624 - 9035 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 24 - 636 / 1200 - 24 - 636 / 1200 - 10115 8420Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hydro Set Packer Liner 4920 7" 5465 - 10385 5042 - 8613 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Sternicki, Oliver R Oliver.Sternicki@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4301 Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9075 Sundry Number or N/A if C.O. Exempt: 320-252 Junk Packer Printed and Electronic Fracture Stimulation Data Renew Suspension Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028310 PBU B-02A 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 /LQHU By Samantha Carlisle at 1:33 pm, Jun 30, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.30 13:21:58 -08'00' SFD 7/2/2020RBDMS HEW 7/1/2020 DSR-6/30/2020MGR02JUL2020 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:196-111 6.API Number:50-029-20066-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028310 Property Designation (Lease Number):10. 8. PBU B-02A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Renew Suspension Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12283 Effective Depth MD: L-80 11. June 30, 2020 Commission Representative: 15. Suspended 5 Contact Name: Mcmullen, John C Contact Email: John.McMullen@bp.com Authorized Name: Mcmullen, John C Authorized Title:Well Interventions Superintendent Special Projects Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9075 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10115 / 8420 No SSSV Installed Date: Liner 4920 7"5465 - 10385 5042 - 8613 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 32 - 112 30 - 2201 30 - 2201 14. Estimated Date for Commencing Operations: BOP Sketch 32 - 2316 Conductor 3090 / 3450 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Packer 10400 - 12165 8624 - 9035 4-1/2" 12.6#24 - 636 / 1200 - 10171 Intermediate 725 725 725, 800, 10124 1224 32 - 2316 1500 / 520 16" 13-3/8" Contact Phone:+1 9075644711 Date: 1540 / 1950 2053 2320 / 15020"Surface 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 80 30"32 - 112 Intermediate 2171 Intermediate 4526 28 - 4554 28 - 4331 5637 9-5/8" x 10-3/4" x 9-5/8" 26 - 5663 26 - 5196 6870 / 4430 / 6870 4760 / 3390 / 4760 Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. /LQHU By Samantha Carlisle at 3:29 pm, Jun 11, 2020 320-252 Mcmullen, John C Digitally signed by Mcmullen, John C Date: 2020.06.11 14:44:46 -08'00' 10-404 1.Monitor annular pressures daily to give an indication of any communication established to the reservoir (note that TxIA is in communication so IA pressures will monitor Tubing and IA). 2.Injectivity test on the TxIA annually. 3.Should communication to the reservoir be established and injectivity be sufficient to allow for a fullbore reservoir abandonment then a plan to perform that abandonment will be submitted to the AOGCC via Sundry. 4 The well will remain in Suspended Status until a final P&A program is agreed upon with AOGCC. SFD 6/11/2020 September 30, 2025 MGR12JUN20 DSR-6/11/2020 Per 20 AAC 25.110 Suspended Wells: (e) Next inspection shall be conducted 24 months before Yes n Required? Comm. 6/29/2020 dts 6/28/2020 RBDMS HEW 7/1/2020 BP Exploration (Alaska) Inc. John McMullen., BPXA Well Integrity and Interventions Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 June 9, 2020 Mr. Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well B-02A (PTD # 196111) Application for Renewal of Existing Suspension (10-403) Dear Mr. Price, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well B-02A on 03/07/2020 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: x Suspended Well Site Inspection form documenting the pressures and site condition x Wellbore diagram illustrating the current configuration of the well Prudhoe Bay Unit well B-02A was suspended on 03/01/2010. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. In late 2019 through early 2020, under sundry #319-486 work to P&A B-02A was unsuccessful at gaining access to the 4.5” tubing in order to place cement laterally above the packer at 10115’. The well is mechanically sound with a plug set at 10124 ’and 10149’in the 4.5” tubing and the OA, OOA and OOOA are cemented to surface. The following is the monitoring and remediation plan for the well: 1. Monitor annular pressures daily to give an indication of any communication established to the reservoir (note that TxIA is in communication so IA pressures will monitor Tubing and IA). 2. Injectivity test on the TxIA annually with an anniversary date of 05/24/2020. 3. Should communication to the reservoir be established and injectivity be sufficient to allow for a fullbore reservoir abandonment then a plan to perform that abandonment will be submitted to the AOGCC via Sundry. Based on these conditions and the inspection on 03/07/2020 Prudhoe Bay Unit well B- 02A meets the provisions required in 20 AAC 25.110 (a)(1). BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on )qpp Attached is an Application for gp Sundry Approval (10-403) with a technical justification summarizing the information on pp the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). If you have any questions, please call me at 529-9129 or Ryan Holt/ Andrew Ogg at 659-5102. Sincerely, John McMullen BPXA Well Integrity and Interventions Manager Attachments Technical Justification 2020 Suspended Well Site Inspection form Wellbore Schematic the current status and condition of the well Prudhoe Bay Well B-02A (PTD 196111) Technical Justification for Renewal of Suspended Status June 9, 2020 Well History and Status Prudhoe Bay Unit well B-02A (PTD 196111) was suspended on 03/01/2010. A RWO in late 2006 was unable to mill a cement donut left in the inner annulus during a March 2003 OA circulation squeeze that took returns up the IA. The rig was making slow progress washing over the 4.5" tubing and cement and started getting metal returns indicating damage to the 9.625" production casing. The rig shut down operations after 11 days and RDMO. The rig left B-02A with: x A Baker Quickdrill composite plug and a HES Fasdrill composite plug in the 4.5" tubing at 10124' and 10149’, x The tubing cut and pulled from 1200', x A HES Fasdrill composite plug set in the 9.625" casing at 800' with 75' of cement on top of the plug and x 636' of 4.5" workstring. In late 2018 work began to P&A B-02A. The 9.625” plug and cement was milled to gain access to the 4.5” tubing stub so that cement could be placed laterally above the packer at 10115’. Multiple attempts were made, but coiled tubing was unable to access the 4.5” tubing. A CMIT TxIA pressure test on 05/24/2020 to 3000 psi lost 82 psi and 57 psi during the first and second 15 minute intervals. Being unable to enter the 4.5” tubing stub and unable to pump into the well due to the tubing plugs the well cannot be P&A’d at this time. The following is the monitoring and remediation plan for the well: 1. Monitor annular pressures daily to give an indication of any communication established to the reservoir (note that TxIA is in communication so IA pressures will monitor Tubing and IA). 2. Injectivity test on the TxIA annually with an anniversary date of 05/24/2020. 3. Should communication to the reservoir be established and injectivity be sufficient to allow for a fullbore reservoir abandonment then a plan to perform that abandonment will be submitted to the AOGCC via Sundry. The well is mechanically sound as proven by a pressure test on 05/24/2020. In the current state 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, 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 Wellhead and Surface Location Prudhoe Bay Unit well B-02A is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no T ppp Being unable to enter the 4.5” tubing at this time. stub and unable to pump into the well due to the tubing plugs the well cannot be P&A’d g g g sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O/OO/OOO = 1/25/125/75/50 psi recorded on 03/07/2020 and are stable. Request BPXA requests approval for renewal of the existing suspension status for B-02A. 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:196-111 6.50-029-20066-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12283 725 724 10115 1101, 1224 725, 800, 10124 8420 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 30" 32 - 112 32 - 112 Surface 2053 20" 32 - 2316 32 - 2316 2320 / 1500 Intermediate 2171 16" 30 - 2201 30 - 2201 Intermediate 4526 13-3/8" 28 - 4554 28 - 4331 3090 / 3450 1540 / 1950 Intermediate 5637 9-5/8" x 10-3/4" x 926 - 5663 26 - 5196 6870 / 4430 / 6870 4760 / 3390 / 4760 Perforation Depth: Measured depth: 10400 - 12165 feet True vertical depth:8624 - 9035 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 24 - 636 / 24 - 636 / 10115 8420Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hydro Set Packer Liner 4920 7" 5465 - 10385 5042 - 8613 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Sternicki, Oliver R Oliver.Sternicki@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4301 Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9075 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Suspend Inspection Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028310 PBU B-02A 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 /LQHU By Samantha Carlisle at 3:23 pm, Jun 11, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.11 14:59:24 -08'00' MGR12JUN2020 DSR-6/11/2020 RBDMS HEW 6/12/2020 SFD 6/17/2020 ACTIVITYDATE SUMMARY 3/6/2020 T/I/O/OO/OOO = 0+/40/130/80/80. Temp = SI. Pre SU well inspection. No flowlines. Dry hole tree w/ ASV installed. Temporary scaffolding installed around well. Area around well is clean and free of debris. Wellhead, wellhouse, floor grating, and cellar are clean, dry, and free of debris. Well ID sign installed on wellhouse. ASV = C. SV, MV = C. IA, OA, OOA, OOOA = OTG. 02:45 3/7/2020 1/25/125/75/50. LTSI. Performed AOGCC suspended well inspection. Witnessed by Guy Cook. SV, SSV, MV = C. IA, OA, OOA, OOOA = OTG. 09:30. Daily Report of Well Operations PBU B-02A B-02A 4-1/2" HES “XN” NIP, ID = 3.725" 4-1/2" 12.6# L-80 NSCT Workstring636' 625' Top of Underreamed CMT 12/03/18746' CTM 800'HES ‘Fasdrill’ Bridge Plug 1720' 1415' Jet Cut, 4-1/2" Tubing Jet Cut, 4-1/2" Tubing Chemical Cut, 4-1/2" Tubing HES 4-1/2" ‘Fasdrill’ Bridge Plug 10048' NOTE : WELL WAS LEFT W/ 9.8 NaCl BRINE IN ANNULUS AND 20BBLS DIESEL F/P. 10124' SUSPENDED Suspended Well Inspection Review Report InspectNo: susGDC200307120345 Date Inspected: 3/7/2020 Inspector: Guy Cook Type of Inspection Well Name: PRUDHOE BAY UNIT B -02A Permit Number: 1961110 Suspension Approval: Sundry N 310-027 ' Suspension Date: 3/30/2010 Location Verified? 0 If Verified, How? Other (specify in comments) Offshore? ❑ Subsequent Date AOGCC Notified: 3/6/2020 Operator: BP Exploration (Alaska) Inc. Operator Rep: Ryan Moore Wellbore Diagram Avail? Photos Taken? Well Pressures (psi): Tubing: 1 Fluid in Cellar? ❑ IA: 25 BPV Installed? ❑ OA: 125 VR Plug(s) Installed? ❑ Wellhead Condition Fair to good condition. The OA valves are inoperable as one is missing a handle and the other cannot be actuated due to corrosion/rust or freezing. There are obvious old signs of hydrocarbons on the wellhead flanges and valves. Lots of dirt/gravel on the valves as well. Condition of Cellar The cellar appeared to be dry and free of hydrocarbons, but difficult to see as the cellar is quite deep and the view is partially blocked by annulus valves. Surrounding Surface Condition The surrounding location was snow/ice covered, but appeared to be clean. Comments Location was verified by a pad map of PBU B -pad. There is an ODA and an OOOA on this well also. T/IA/OA/OOA/OOOA = 1/25/125/75/50. This well is slated for a P&A in the next few months. Supervisor Comments NaVs �i tiP 3 � ,-3 �kq(Ze vJ Wednesday, March 18, 2020 V. -- Ift NNW W!'WAIM _ ,nn%— '�► ff i r +JA �fF,� f 4 40 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions & Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU B -02A Permit to Drill Number: 196-111 Sundry Number: 319-486 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P J Price Chair DATED this day of November, 2019. RBDMV� NOV 1 01019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 OCT 2 3 2019 1. Type of Request: Abandon 0 Plug Perforations ❑ FractureStimulate ❑ Repair Well ❑ pow, IV ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program H Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development M 5. Permit to Drill Number: 196-111 0 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612Stre[igrephic ❑ Service ❑ 6. API Number: 50-029-20066-01-00 - 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? e. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU B -02A - r 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028310 • PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12283 9075 725 725 725,800,10124 1224 Casing Length Size MD TVD Burst Collapse Conductor 80 30" 32-112 32-112 Surface 2053 20" 32-2316 32-2316 2320 / 1530 15001520 Intermediate 2171 16" 30 - 2201 30-2201 Intermediate 4526 13-3/8" 28-4554 28-4331 3090/3450 1540/1950 Intermediate 5637 9-5/8" x 10-3/4" x 9-5/8" 26-5663 26-5196 1 6870 / 4430 16870 4760 / 3390 14760 Liner 4920 7" 5465 - 10385 5042 - 8613 8160 7020 Liner 2109 4-1/2" 10174-12283 8482-9075 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size.Tubing Grade: Tubing MD (ft): 10400 - 12165 8624-9035 4-1/2" 12.6# L-80 24 - 636 11200 - 10171 Packers and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 10115 / 8420 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic m 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: November 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned H 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Aras be deviated from without prior written approval. Contact Email: Arae. Worthington@bp.com Authorized Name: Worthington, Ares Contact Phone: +1 907 564 4102 Authonzed Title: Interventop & Integrity Engineer Authorized Signature: Data: I/ I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: lq-u Plug Integrity 11 it^y�� 11BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other:7CLd O ✓Ht 0-n QS [XLSC�� r�i �r.t� �r �d/A Irl oL ►'k- C K Post Initial Injection MIT I'd? Yes ❑ No ❑ Spacing Ex ion Required? Yes ❑ No IV Subsequent Form Required: l�..4.��•y1 APPROVED BYTHE /► _ ' ` Approved by: COMMISSIONER COMMISSION Date ` V11 mel ORIGINAL RBDMS vNOV 18 2019 I Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate B-02 Plug and Abandon Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Brian Glasheen (907) 564-5905 Expected Start Date November 15, 2019 RECEIVED OCT 2 1 2019 History Originally drilled and completed in 1977. A RWO in 2009 failed to fish the partially cemented production tubing in 2007 and the work was suspended. There are no plans for this wellbore therefore the well will be P&A'd. Objective Place cement plugs in the well. The well was originally Sundried to remain in suspended status until final removal of the casings and welding of marker plate 3' below original tundra level but this work is now included in this Sundry application therefore the new designation is for P&A. Procedural steps DONE: Red dye returned to surface @ 1.5 bbls away DONE: Good cement returns at 3.5 bbls away, hesitated and pumped a total of 8 bbls of cement DONE: CMIT TxIA Passed to 2680 psi 10/07/18 '- Coiled Tubing 1. Mill through Cement and mill hole through 9-5/8" CBP @ 800' MD. 2. Attempt to get into top of milled tubing @ 1200' MD either slick or with motor and mill. 3. RIH to top of CBP @ 10,124' MD. 4. Drop ball to disconnect motor and mill (if these are part of the BHA) or pump through nozzle laying into tubing and IA @ 1:1 t➢ \700 bbls 15.8 ppg Class (n; cement (40 bbls excgss) 1 I 51, I)134- qy ROG�,C_ �A�'arCcw�.�w�t �v�.S Cement DesTan: c,tiv� p i-aC , BHST — 30 deg F BHCT — 40 deg F • Cement: • Density: • Thickening time: • API Fluid Loss: • Compressive Strength: • Pump time: • Volume: Class G Unislurry cement — mix on the fly 15.8 ppg 3to5hrs 40-200 cc (20-100 cc/30 min) Minimum of 2000 psi 8 hours at assumed rate of 1.5 bpm 700 bbls (pumpable) Contingency #1 CT Cement (If CT cannot get into tubing stub but can pump into the wellbore below) 1. Pump cement Fullbore or through nozzle @ 1200' MD bullheading into the well. ➢ 1000 bbls 15.8 ppg Class G cement (340 bbls excess) ➢ After cement reaches 500 psi squeeze pressure lay cement 1:1 from 1200' MD to surface in �n tubing and IA. _( Q 66— 1' �t1�5� �c��.�TJ / r 'r`mV,4f m i� hrSC.e.�� Contingency #2 CT Cement (if CT cannot get into tubing stub and cannot pump into the wellbore below) 1. Pump cement through nozzle @ 1200' MD laying into tubing and IA @ 1:1 ➢� X120 ' bbls 15.8 ppg Class G cement (30 bbls excess) ns -. C//. ,4- c A 6 G - cc -4 Contingency #3 CT Cement (if CT cannot get past cAent or CBP @ 725' MD) 1. Pump cement through nozzle @ 725' MD laying into tubing and [A@ 1:1 ➢ 63 bbls 15.8 ppg Class G cem nt (10 bbls excess) f dCe /J car` "-'-5e-r C� Special Projects 1. Cut off all casings and wellhead 3' below original tundra level. Top off all annuli and tubing with cement as needed. Install marker cap on outermost casing string with the following bead welded to the cap. Photodocument cement to surface and cap installation. AOGCC to witness cement to surface and cap ms a BP Exploration AK, Inc B -02A PTD # 1961110 API # 50-029-20066-01 KB. E_EV= 69.65' BF. EL.EV= 40.57' KOP= 2750' Max Angie = 32 @ 10879 C 08/17/97 13-318' CSG, 680, K55, D = 12.415" 4645' 9-5/8' x 10-3/4' X-Ovar 2380' 10-314" CSG, 55.50, N-80, .0925 bpf, 9-= 9.76' 2380' X 7' BKR LNR HGR D = I. 7" X 1 4-1r2- lt1 , 12.60, 1-80_0152 bpf, D=3,958' 1 7"X 4-1/2" TNV S -e PKR EE BACK, D = 3 850" 10174' TMIOM t,ER WNGPR I'1 .3972^ ' J 10185•. 1 7"LNR 29#. 13 -CR -80. .0371bpf, U 6. 184"_-10386'-- FIISORATDN SUM6MRY REF LOG: AWS %iCS 07Y29,% ANGLE ATTOP PERF. 48 @ 104W Mte: Refer to Production OB for historical perf data SIZE' SPF NTENAL Opn15Gz DATE 2" 4 10400 -10410 C 08/17/97 2' 4 11920- 11940 O 10(01199 33/8' 4 11960 - 11970 O 0325197 3318' 4 11970-11990 O 1D/13/96 2-118" 4 12012- 12032 O 0929/96 1.56- 4 12040 - 12050 S 08/01198 2' 4 12090- 12110 O 10/01/99 3318' 4 12125-12145 O 0325197 3318' 4 12145-12165 O 10/13196 2' 1 4 12140 - 12160 O 1 092&1% B-02 Current YON 16 'c25' 1-1,2^RES "XN"NIP, d)=3.72S" 036' 4-1,?."12.6# L� O N S C T W OLu=J'g 725' To �., Susp. Phg 600' RES'Fandril'Biiige Pltg 120D` 1tiP,Cur4-L2"'11ibing 1415' JetC ut: 4-1/2^Tubing 1720' Jet C ut, 4-1,L:^7Lbhg NOTE :W ELL WAS LEFT W /9.6 NaC1BRNE N ANNULUS AND 20BELS DIESEL F/R. tti• 7 ,a 10046' Chem ta1Cu44-1/"Tubing EES 4-1/2"Faadrill' E1'ijge Phg 10104' 4-112"HESXMP,D=3.813" 10116' !—(7"X41/2`BKR S-3 PtCR D -3.E 10136" 4-112" HES X MP, D = 3.813" 10159";—{4-i/2" Hv XN NV, D = 3.725" 10171' 4-il2" WLEG, D = 3.958" 1038 4-12'AVA UN RETR PATCK D=2.441' TOTAL LENGTH= 35' 7' ( 08/17/97 ) I Frim I-1 12160' I 4-12' LNK 12.80, 13.0,.0152 bpf, D = 3.959' f- DATE REV BY COMMENTS DATE REV BY COMMiNIS Pf4JDHDE BAY UHT V1E.L: B -02A PERMITNo:1961110 API M1: 50029-20066-Ot SEC 31, Ti 1N R14E 961' SNL 8 1598' AE L 11109177 IHTIALCOMPLETION 08/19!90 = WMTHACK(&02A) 0923108 0.16 BUSPEH7®(IT02A) ,11103116 ALWJMC CORK-CTFD 10--314" CSG MATERIAL BP Exploration (Alaska) CAWRON KB. B -EV = 68.68' BF. ELEV = 40.57' KOP= 275V Msx Angle = 32 @ 10879!, x c G. 55.5#, *00, .0925 bpf, O -9. 7" LNR, 269, L-80..0383bpf, D 6.276" 9-516" X 7- MR Rff27 TIMACK D — 7- 9-.5/8'X7 BKR LNIt raGR D_ 6. i1 112' 1DG, 15' LA L ASSY =a=IQra 3922" B-02 P&A N 16 412"RES"XN"NSP, Yt 4 10400-104t0 636' }12"12 by L -O NSC'T W o,kstrng - 725' TC E_Susp.Phg 4 800' HES 'Fasdrlll'Bi je Phg 1224 1200' TJp.CUt4-12"7Ubng 3-38' 1415' SetCut,4-1/2"nbhg 2098' - . 1720' Jetr at, 4-12"TUb±x3 33/8' Fullbore cement from Surface to 694 21 M1300' >_-1/8' MD in tbg, IA, and OA P&WORA'IM SLMAIZY p' REF LOG: AVMS BHCS 07129 [j ANGLE AT TOP PHS: 48@1 Note: lifer to Roduction DB for historic SIZE SPF �NTH7'/AL �Opn/Sgz 2" 4 10400-104t0 C - 2" 4 11920 - 11940 O M1-11S'1'(:f X:i!a -J.II73".J 3-38' 4 11960-11970 0 33/8' 4 11970-11990 0 >_-1/8' 4 12012-12032 O 1.56' 4 12040- 12050 5 2' 4 12090 - 12110 O 33(8' 4 12125 -12145 O 0325/97 3318' 4 12145-12165 O 10/13+96 74 12140 - 12160 O 092&96 Fullbore cement from 2300' MD to — 2800' MD in tbg, IA, and OA 10048' ChembalCut,4-12"2Ubitg 10124' HHS- 4-1(2-"Fasdrlll' Bulge Phg A) KDA D -12A) W;F lolls' ..�7 X41.;'rKa ? F^•., :J 3SSr5� 16138') M1-11S'1'(:f X:i!a -J.II73".J 10154' _ -6-VY Frfi ; XN NIP, ¢L - 72s 10386' I LBS 1,14K 12-M, 13-C,.0152 bpi, D = 3.9513' _]-1 12283' iS:V AFNTS GATE RE! BY COWAENTS Pf41DFK)E BAY LUT WELL: 602A PHiA4'I'Fh: '1961110 AR Pb: X029-2006601 SEC 31, T11 N R14E, 961' SPL & 1598' WH. TION A) KDA D -12A) W;F ALM;4" CSO M4THilAL BP 6cploration (Alaska) TTTZE= 'CAMERON FALLFIEAB= ACEVOY ACTT ATOR= BAKER KB. H-27 = 68.69 BF. 8F1= 40.57' KOP= 275U Max Angle = 32 @ 10879 ) 9-518' x 10.3/4" X -Over 3/4' CSG, 55S#, N-80..0925 bpf. _D = 9-5/8' X 7' BKR LMR B-02 P&A (Contingency #2) T._ X 47 V:,' iNVTE$ACK PKR W! SEAL ASSY 1016T t-1/2TSG, 12 6k L80, 0152 bpf, D ` 3.958' 10169' I-XM1/2'7'NY S -B HtiilEC13ACK, D=3.85Q' -. 10174' TNV DTH:INFR Ft4 NGE'?, D=3922' L 7" LrBa; 29#.13 -CR -80. D3716pf, D-6.184' P23 0,226' -..-HIWORATION Sl*jMRY D)_ REF LOG: AWS BRCS 0712 D ANGLE AT TOP PELF: 48 @ i Note: Peter to Production DB for historic SIZE SPF MESIAL OpnlSgz 2" 4 10400 - 10410 C 2" 4 11920- 11940 0 3318' 4 11960 -11970 0 3-318' 4 11970-11990 0 2-1/8' 4 12012-12032 0 1.56' 4 12040- 12050 5 2' 4 12090 -12110 O 3-3/8' 4 12125-12145 O T96 97 3-3/8" 4 12145-12165 0 2' 4 12140 - 12160 O 09!28196 bZb" 3-1/2—HES"XN"I; M,D=3725" 7TFINment from Surface to 1200' ID in tbg, IA, and OAg Mill 1415' JetCv4-1/2"`lbbit9 JetCut. 4-1/1"iLbkg OTE :W ELLWASLEFTW/9.8NaC1BRNE ANNULUS AND 20BBLS DIESEL F/P. 10 Chem -i/-,'t,41ill'22C2i9 10124' xe54-12"'Fasdrill'a�ge plrg 10386' DATE REV BY COM+1ENi5DATE T REV BY IXN:AfNI'S i 11M3777 INITIAL COMPLETION ��] 1 Oamw SIDETRACK(B"02A) 0923109 D-16 SESPEdDM(602A( 11/03/16 ALWJME CORRECTED 10-3/4' CSG MATE3IAL IMP, D=3.813' 1 NP, D = 3.725 D= 3.958" LENGTH = 35' 7' D=3.95611- 12283' PR UDHOF BAY tM WELL: B -02A Puf No: r1961110 ARI No: 50-029-20066.01 THIN R14F, 961' SNL & 1598' WE - BP Exploration (Alaska) TRM= . CAMPRON Yx¢JJ"CfUP N VVT ACTUATOR= BAKER KB. AEV = 68.68' BF [1-V= 40.57' KOP= 27W WX Angle = 32 @ 10879 Datum MD= 10983' Wtum TVD= 8800'SS 9-5/8' x 10-314' X -Over 9-5/8' X T' B-02 P&A (Contingency #3) 644" t 4-1,2"HEs' "XN' NAY, r = 3.'125" Cement from Surface to —725fri from Surface to —725' 1M in tbg, IA, and OA _ 1415' seecut,4-1/.IT.T bhg 12.415" _ 1720' JetCut '4112"Tvbbg 2 ,2098' - 6945' 1MD NOTE :W ELL W AS LEFT W /9.8 NaC1BPIQE =9.78' -tANNULUS AND 20BBL5 DIESEL F/P. 7" X TN'tTF$ACK RCR W! SEAL ASSY 1016T } Cd_i!I Thr' 126# 180, 0157 Fp D 9681 10169'.._: 1-i- X 4-1 tT" 1NV S6 FKRlTEBACI( D =3.850' j 10174' � TNY U 01 Lrvf-R I IF N(3Bi, f7' LNR 29#, 13 -CR -80, 0371bpf, D=6 1a4" pZ3 DATEF7LV BY kUQ-QKA I DN SLYffl1AKY 10048' Chem talCut 4 IP—,i hbg -- 68119196 10124' AES 4-1i2"'Fastlrill'E>ilge FLg 10104 4-1/2"HESX NIP,D=3.813' 69123109 616 J 11103/16 ALAM ANGLE AT TOP FEW 48@1 1 Q115' T X 4-112` BKR S-3 PKR D� 3.875' We P10138'4-12' MES X W D= 3.813" 10169' 4 -1 -12 --HES XNNF. D=3.725' SPF DATEF7LV BY kUQ-QKA I DN SLYffl1AKY Dr 10386• 68119196 R�LOG: AWS MCS 0729!9 69123109 616 J 11103/16 ALAM ANGLE AT TOP FEW 48@1 We Refer to Roduction DB for histwic SPF SPF MHiVAL QpNSgz `. 2' 4 1(4100-10410 C 2" 4 11920 -11940 O iN8'. 4 11960-11970 0 - 33/8' 4 11970 -11990 0 ?-118' 4 12012 -12032 O 1.56' 4 12(40- 12050 5 2- 4 12090 -12110 0 iNg' 4 12125-12145 0 r1325/97 L3/8" 4 12145 -12165 C) 10/13/96 4-12' LW 12.86, 13-' 2" 4 12140-12160 ! G i 0928196 . DATEF7LV BY (X]443415 hil-. REV BY COM.£N1S 11109/77 INTIALCOMPLEf10N 68119196 SIOEIRAGK(&02A) 69123109 616 Sl15PIRMED(M2A) 11103/16 ALAM COFUEU-7 D 103/4' C,SG WATH4AL wU4 .441" TOTAL LH4GTH = 35'7" ( 08117/97 I 12283' PRJDHDE BAY LWT W01: &02A PERW W:'1961110 AR W: 50-029 20066 01 T11K R14E, 961' SNL 8 1598' WH. BP 6lploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS, I 6 *_ A. " 10 7 SEP 11 -Ut9 1. Operations Performed 80 Surface Total Depth: measured 12283 feet true vertical �: Abandon El Plug Perforations [I Fracture Stimulate ❑ Pull Tubing❑ Operationfi`s' ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrili ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 1 Exploratory C] 5. Permit to Drill Number. 196-111 3. Address: P.O. Box 196612 Anchorage, 15001520 30-2201 AK 99519-6612 Stratigraphic ❑ Service 1 6. API Number: 50-029-20066-01-00 7. Property Designation (Lease Number): ADL 028310 8. Well Name and Number: PBU B -02A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 5465-10385 5042-8613 8160 7020 PRUDHOE BAY. PRUDHOE OIL 8462-9075 11. Present Well Condition Summary: 80 Surface Total Depth: measured 12283 feet true vertical 9075 feet Effective Depth: measured 752 feet true vertical 752 feet Casing: Length: Size Conductor 80 Surface 2284 Intermediate 2171 Intermediate 4526 Intermediate 5637 Liner 4920 Liner 2109 Perforation Depth: Measured depth: True vertical depth: 30" 20" 16" 13-3/8" 9-5/8" x 10-3/4" x 9 7" 4-1/2" None feet feet Plugs measured 752, 800, 10124 feet Junk measured 1101, 1224 feet Subsequent to operation: Packer measured 10115 feet Packer true vertical 8420 feet 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP R1 SPLUG ❑ MD: TVD: Burst: Collapse: 32-112 32-112 32-2316 32-2316 2320 / 1530 15001520 30-2201 30-2201 28-4554 28-4331 3090/3450 1540/1950 26-5663 26-5196 6870 14430 / 6870 4760 / 3390 / 4760 5465-10385 5042-8613 8160 7020 10174-12283 8462-9075 8430 7500 Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Hydro Set Packer true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): (13. descriptions including volumes used and final pressure: 24 - 636 / 1200 / 101 24 - 636 / 1200 - 8460 10115 8420 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspentletl Subsequent to operation: 14.Attachments: (required per 20MC 250]0.25.071.&25.283) Daily Report of Well Operations 21 Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 15. Well Class after work: Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP R1 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: N/A Authorized Name: Lastufka, Joseph N Contact Name: MontgomeryTravis J Authorized Title: /'JIM Specialist /—N Contact Email: Travis.Montgomery(a)bp.com Authorized Signature: Date: (A I' 1 /' 64 Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 "r 'X11'7 �7 RBDMS_1f0�,1SEP 112019 Submit Original Only Daily Report of Well Operations PBU B -02A T/1/0/00/000 = SSV/220/50/50/50. Temp = SI. Pre suspended well inspection. Dry hole tree w/ ASV installed. No scaffold or flow line. Temporary scaffold installed. McEvoy wellhead w/ dry hole tree, CIW ASV w/ Baker actuator (appear to be in good condition). 7" of fluid in cellar @ 12 o'clock (fluid is discolored with a slight sheen, faint smell of diesel in cellar). Trash & debris removed from well house & cellar less the sombrero buried in the mud. -16" conductor @ 2 o'clock position in cellar. Pits have several feet of water with no sheen. Multiple puddles on the pad with no sheen. Signage installed on well house. Area surrounding the well house is dry, level gravel. 8/1/2019 ASV = C. SV, MV = LOTO. IA, OA, OOA, OOOA = 0. 23:59 T/1/0/00/000 = SSV/150/50/55/50. Temp = SI. WHPs (AOGCC Witnessed Suspended well inspection). State witnessed by Brian Bixby. Dry hole tree w/ ASV installed. Wellhouse clear of any trash and debris. Took pics. 8/17/2019 ASV = C. SV, MV = LOTO. IA, OA, OOA, OOOA = OTG. 10:30 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: B -02A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1961110 API Number: 50-029-20066-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 3/1/2010 Surface Location: Section: 31 Twsp: 11N Range: 14E Nearest active pad or road: B Pad 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: (, I#^.^ Pad or location surface: C- (44?% Location cleanup needed: Pits condition: Surrounding area conditic Water/fluids on pad: Discoloration, Sheens on Samples taken: None Access road condition: Photographs taken (# and 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: cast,,, Cellar description, cond jo Rat Hole: til A Wellhouse or protectiv ba Well identification sign: Tubing Pressure (or casino Annulus pressures: Wellhead Photos taken (# Work Required: None fluids: r- /. i Operator Rep (name and signature): Josh Prowant AOGCCInspector:gI Other Obs rvers: 8/17/2 Inspection Date: 019 AOGCC Notice Date: Time of arrival: I b.?o Time of Departure: Site access method: Access road G24' ., ' C-24BPBI B-3aA G-U5RP " _�laxA_C-1`- 12CP51-" C'39A 2SBPB1 _07-2S CJ-23Q - GC 3C-3 L 2APB1.. :: C-2@B C-2'9A i a7-13BOT-10A ": C-088 a7-1"�,A � C-28A GC-3 CzC 3A C C ae�— .COC. C`L`--12A - j a7-2SH 307 CMA C� 8AP61 Lc-lo .. ? C-1 a6 3'x '.1 C-34SPE1, fiC$3C C C-27B 13 C C22A B-a5 C-27C �'W-,MA EDPBI -C-10, " C-22 B-0-6_ _ F C-27 —_07-30 C-28 B ...`. 29 C 27APBt- B-07; @-a 3 =Bas &a3A _ 17 B-04 C-2 A a7-1 a t3(:PB1 j@-704A a7-9a - B-04APH7 S-MA - .. i B-07A G 6-08A. L B-2aA a7-a9P61 . B-27 - &13 _ _ &20 B-27G PB4 :.. 6.2TGPE�` 07-35 5 7C B-18 B-27A — _ B-278 B-ofA -.. 3? a3A 0 07-09A .. B-1'.I-a� g &03P61 LS B-16APB1 - o7-83APB1 a. 1' - jAD ;B a� a21 "I 2 B 22,A x-29 I F L 6;22rar_ U-2_.A ' 07-4)3B C 6-35 a7-11A3 - 31 I B-14A t 07-25 H-29AP61 � ' 'T B-14APB2 c 6-01 B-2:A 5-141 E- < 8.298-. ,14 Bn1_A. a7- v �- _M1'27 B-14APB1 - ;r &138 y }' L.07-23A B-13B &31 =6-286 iti; a7-12 B-j 3-Ato B-25 3 9-09 �4i &faA 6-11 14-01 `B-10 }` s 3 7A 14-02" X-17 ? E-11AXX L B-34 - - 14-DIA B-32 1 B-32A X-25X-01 I (� 8 X-4)2`.6-280 �i 5 r_ X-15, 9 X-a4,A 4 L94-23 - X-04 X-24 X-16 f IV TRE= 7-1/16"CAM91ON WELLHEAD= MCEVOY ACTUATOR= BAKf32 OKB = 59.77 RIF ELB/ = 88.5' BF. ELEV = 40.T KOP= Max Angle = Datum MD= 2750 82° @ 10879' 10963' Datum TVD = 8800'SS 9-5/8" - SUSPENDED B -02A 3.70" STUB 9.76" -NR, ZM, L-80, .0383bpf, D = 6.276' 'X 7' BKR PKR / TIEBACK, D = 7.50' 9-5/8' X 7' BKR LNR HGP, D = 6.18" 9-5/8" CSG, 47#, N-80, D = 8.681- 7"X .681' 7"X 4-12" TNV TIEBACK PKR W/ SEAL ASSY1016T 4-1/2' TBG, 12.6#, L80, .0152 bpf, D = 3.958' 10169• 7' X 4-1/2' TNV S-6 PKR?®ACK, D = 3.850"10174' TNV DTH LNER HANGER, D = 3.922' 10185' 7" LNR, 29#, 13 -CR -80, .0371bpf, D=6.184"10386' _ PEiFO RATION Sl1 UMITY REF LOG: AWS BRCS 07/29/96 ANGLEAT TOP PERF: 48@104W Note: Pefer to Reduction DB for historical pert data SIZE SPF I MHRVAL Opn/Sgz DATE 2" 4 10400- 10410 C 08/17/97 2" 4 11920 - 11940 c 10/01/99 3-318" 4 11960-11970 C 03/25/97 33/8" 4 11970-11990 C 10/13/96 2-1/8" 4 12012 - 12032 C 09/29/96 1.56" 4 12040- 12050 S 08/01/96 2" 4 12090-12110 C 10/01/99 3-3/8" 4 12125 - 12145 C 0325197 3-3/8" 4 12145- 12165 C 10/13/96 2" 4 12140 - 12160 1 C 09/28196 625' I 41/2"HES "XN" NIP, E = 3.725" 636' 4-112"12.6# L A 0 NS C T W O&sb:hg 746'CTM TOP OfUndeneam ed CM T 12/03/18 800' H E S'Fasdrill' B nilge P lig —1101' i/3 OF 4-1/2' 7BG LE -7 N HOLE, MLL® 14-15---1 Jet Cut., 4-12" Tubing 1720' JetC ut 4-1/2^Tubing 2204' 4-1 /2' HES HXO SSSV NP, D = 3.813 NOTE :WELL WAS LEFT W /9.8 NaC1BRINE IN ANNULUS AND 20BBLS DIESEL F/P. ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2977 2969 16 K0 2 -LS DONE M 20 03127/03 5 5449 5029 39 KGB -2 -LS SO M 16 03/27/03 4 7466 6432 42 KGB -2 -LS OM1' M 0 09/18/96 3 8776 7378 43 KGB -2 -LS 0M1' WT 0 09/18/96 2 9510 7915 43 KGB -2 -LS OMY M 0 09/18/96 1 10078 8323 43 KGB -2 -LS OMY M 0 09/18/96 10386'412-AVA UVV RETR PATCH, D= TOTAL L84GTH = 35'7" ( 08/17/97 I PBTD I 4-12" LNR 12-69,13-C,.0152 bpf, D = 3.958" 1 DATE REV BY COR&g3gM ------- LL0048'j Chem ba1Cu441/21-TUbng 10124' HES 4-1A'-'Fasdnll' BxBge PLg 11/09/77 INTIAL COMPLETION 06/19196 SIDETRACK(B-02A) 10104' 4-1/2" HES X NP, D = 3.813' 09/23/09 0.16 SUSPB'O® (B -02A) 10118' TX4-V2'BKRS3 PKR,D=1 11/03/16 ALIWJ CORIECTED 10-3/4" CSG MATERNL 10138' 4-12'HEBXNP,D=3.813' 10159' 4-1/2' FES XN NP, D = 3.725' 10171' 4-1/2' WLEG, D= 3.958• 10386'412-AVA UVV RETR PATCH, D= TOTAL L84GTH = 35'7" ( 08/17/97 I PBTD I 4-12" LNR 12-69,13-C,.0152 bpf, D = 3.958" 1 DATE REV BY COR&g3gM DATE REV BY COkfAENTS 11/09/77 INTIAL COMPLETION 06/19196 SIDETRACK(B-02A) 09/23/09 0.16 SUSPB'O® (B -02A) 11/03/16 ALIWJ CORIECTED 10-3/4" CSG MATERNL 05/16/18 AV11JM7 L MAT®SUSPB�I]ED WRS 12/17/18 JCF/JMD LA47 AMED CXuIT & PLOT HIOLE PRIJOH OE BAY LUT WELL B -02A PE MT N0: 1961110 AR No: 50-029-20066-01 TI I N, R14F- 981' SNL 8 1598' VVEL BP Btploration (Alaska) Suspended Well Inspection Review Report InspectNo: susBDB190817155832 Date Inspected: 8/17/2019 Inspector: Brian Bixby Well Name: PRUDHOE BAY UNIT B -02A Permit Number: 1961110 Suspension Approval: Sundry R 310-027 Suspension Date: 3/1/2010 Location Verified? If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 8/16/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? ❑O Photos Taken? ❑.i Well Pressures (psi): Tubing: Fluid in Cellar? ❑� IA: 150 BPV Installed? ❑ OA: 50 VR Plug(s) Installed? ❑ Wellhead Condition Good, Flowlines are disconnected. Condition of Cellar Good, small amount of clean water in it. Surrounding Surface Condition Good Comments Wellhead is Locked Out so we didn't get a tubing pressure. Location was verified by pad As -Built Map. ODA = 50psi / COCA = 50psi Supervisor Comments Photos(3) Monday, September 9, 2019 Suspended Well Inspection — PBU B -02A PTD 1961110 Photos by AOGCC Inspector B. Bixby 8/17/2019 2019-0817_ Suspend_ PBU_B-02A_bb.docx Pagel of 2 • of tilt • iot° I//7,. ..v THE STA Alaska Oil and Gas /— , 0 Conservation Commission 2 _ y ALAsKA 333 West Seventh Avenue �ITh, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O '"�++m,;; Main: 907.279.1433 F ALAS— Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington JUN �i)i Interventions and Integrity Engineer %AHMED BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B-02A Permit to Drill Number: 196-111 Sundry Number: 318-199 Dear Mr. Worthington: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, U ,Q✓ / Cathy 11. Foerster --` Commissioner DATED this IT d of June, 2018. RBDMJUN 141018 f STATE OF ALASKA RECEllitD 0 ALASKA OIL AND GAS CONSERVATION COM ION • APPLICATION FOR SUNDRY APPRWLS °�'S 6�/�/��i 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend &I • Perforate 0 Other Stimulate 0 Pull Tubing 0 Change AGGFOO Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Add'I Suspend I21' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 196-111 • 3_ Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development H 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-20066-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Q PBU B-02A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028310 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12283 9075 725 725 725,800,10124 1224 Casing Length Size MD TVD Burst Collapse Conductor 80 30" 32-112 32-112 Surface 2053 20" 32-2316 32-2316 2320/1530 1500/520 Intermediate 2171 16" 30-2201 30-2201 Intermediate 4526 13-3/8" 28-4554 28-4331 3090/3450 1540/1950 Intermediate 5637 9-5/8"x 10-3/4"x 9-5/8" 26-5663 26-5196 6870/4430/6870 4760/3390/4760 Liner See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10400-12165 8624-9035 4-1/2"12.6# L-80 24-636/1200-10171 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 10115/8420 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic B 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development II • Service 4 14.Estimated Date for Commencing Operations: June 20,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended RI 'll 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 III 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington,Aras be deviated from without prior written approval. Contact Email: Aras.Worthington@bp.com Authorized Name: Worthington,Aras Contact Phone: +1 907 564 4102 Authorized Title: Interventions&Integrity Engineer Authorized Signature: /,..,<........7/5 Date: ��./�� 7COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 1 Plug Integrity IV/ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: 1 Post Initial Injection MIT Req'd? Yes 0 No / Spacing Exception Required? Yes 0 No Q Subsequent Form Required: /O— 4-0 n APPROVED BYTHE /1_ /9 Approved by: aetty /Y COMMISSIONER COMMISSION Date: vrrL G//i/6 ' RBDM JUN 141018 l*{,' ORIGINAL . s-.X,;. ,g Sulnit and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • i Casing / Tubing Attachment B-02A Casing Length Size MD TVD Burst Collapse LINER 4920 7"29#L-80 5465 - 10385 5042 - 8613 8160 7020 LINER 2109 4-1/2" 12.6# 13Cr80 10174 - 12283 8462 - 9075 8430 7500 I bp • B-02 Suspend Well Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Wade Boman (907) 564-4674 Expected Start Date June 20, 2018 History Originally drilled and completed in 1977. A RWO in 2009 failed to fish the partially cemented production tubing in 2007 and the work was suspended. There are no plans for this wellbore therefore the well will be P&A'd. Objective Place cement plugs in the well. The well will remain in suspended status until final removal of the casings and welding of marker plate 3' below original Tundra level. Procedural steps DHD/Special projects 1. Pump red-dye pill down OOA and up 000A to determine volume returned/approximate leak depth. Fullbore 1. Pump cement down OOA and up 000A (surface to surface) via the following pump schedule: ➢ 5 bbl MEOH spear ➢ 5 bbls FW spacer ➢ 15.8 ppg Class G cement (volume to be determined from previous step) Cement Design: BHST— 3CI deg F BHCT —40 deg F • Cement: Class G Unislurry cement — mix on the fly • Density: 15.8 ppg • Thickening time: 2 to 3 hrs • API Fluid Loss: 40-200 cc (20-100 cc/30 min) • Compressive Strength: Minimum of 2000 psi • Pump time: 30 minutes at assumed rate of 1 bpm • Volume: TBD 0 • Fullbore 1. OMIT TxIA to 2500 psi Coiled Tubing 1. Mill through Cement and mill hole through 9-5/8" CBP @ 800' MD. 2. Attempt to get into top of milled tubing @ 1200' MD either slick or with motor and mill. 3. RIH to top of CBP @ 10,124' MD. 4. Drop ball to disconnect motor and mill (if these are part of the BHA) or pump through nozzle laying into tubing and IA @ 1:1 > 700 bbls 15.8 ppg Class G cement (40 bbls excess) Cement Design: BHST- 30 deg F BHCT -40 deg F • Cement: Class G Unislurry cement- mix on the fly • Density: 15.8 ppg • Thickening time: 3 to 5 hrs • API Fluid Loss: 40-200 cc (20-100 cc/30 min) • Compressive Strength: Minimum of 2000 psi • Pump time: 8 hours at assumed rate of 1.5 bpm • Volume: 700 bbls (pumpable) � �d cc c "d C c-�— 4 �i - -I-- , cres Contingen y#1 CT Cement (If CT cannot get into tubing stub but can pump into the wellbor below) 1. Pump cement Fullbore or through nozzle @ 1200' MD bullheading into the well. > 1000 bbls 15.8 ppg Class G cement (340 bbls)a ss) > After cement reaches 500 psi squeeze pressi.re lay cement 1:1 from 1200' MD to surface in tubing and,IA. Contingency#2 CT Cement (If CT cannot get intotubing stub and cannot pump into the wellbore below) ll 1. Pump cement through nozzle @ 1200' Tying into tubing and IA @ 1:1 ➢ 120 bbls 15.8ppg p Clas ce nt (30 bbls excess) Contingency#3 CT Cement (If CT of 'et/past cement or CBP @ 725' MD) 1. Pump cement through noz 4�,� 725' MD laying into tubing and IA @ 1:1 ➢ 63 bbls 15.8 ppg Cls§ G cement (10 bbls excess) p ro GIaCvrw>fvi Special Projects 1. Cut off all casings and wellhead -1' below pad level. T p ff all annuli and tubing with cement as needed. Install mar er cap on outermost casing stringith the following bead welded to the cap: BP Exploration AK, Inc o6 eZ r� 5-19tc. 14Z)r- B-02A / N01-1 fy PTD # 1961110 -f 0 w'i fv,t a 5 Tc-7 C v to , API # 50-029-20066-01 C erylt''1l top off t- 07 nn v 11474T-/h kr.)- at 1 .tvb'.z- at d mot vkcr '4p . Note: Final excavation, casing removal to 3' below tundra, and marker plate welding to occur at pad remediation. 2 TREE= • CAMERON WbaLHEAO` MCEVOY • B -0 2 A III U p d a tl✓d 2-12-18 (Z B ) ACTUATOR= BAKER KB.aEV= 68.68' SUSPENDED 09/23/06 -DO YON 16 BE aEV= 40.57' •: KOP= 2750' 625'J. il 4-1/2"HES 'XIV NIP,ID = 3.725" Nfax Angle= 32 10879' .a.'.:: .•' 636' 4-1/2"12.6#L-8O NSCT W cnkstriig Datum MD= 10983' .... 725, T D.0.,S usp.P Lig Datum TVD= 8800'SS :• �� F tf Ng5J8"-Sf TRA(�CVYtT}iWASF f --I 1101'-1224' jit' -•._.•, 800' HES 'FasdrllP Bulge Plug r:its 113 of 4 112'Tubing left in hole,need thru TOP OF COI t AF'SFT)TURING SLUR H 1224' "+... •40,*<, 9-518"X 10-3/4"CROSSOVER - 1968' , it°,'ic_ _ _ %V.':••:,.-: 1415' Jet Cut,4-1/2"Tubing :f } 1720' JetCut,4-1/2"Tubing 16'CIRCULATION STRING H 2192' ' _ ' 20'CSG,94/1334,H-40/K-55 -{ 2308' / 2204' -{4-1/2"HES HXO SSSV NP,ID=3-813" NOTE :W ELL WAS LEFT W /92 NaC 113R]NE 10-314"CSG,55-5#,N-80,.0925 bpf,D=9-76" H 2380' JN ANNULUS AND 2OBBLS DIESEL F/t'. 1 13-3/8"CSG,684,K55,D=12.415" -I 4545' }-___., GAS LFT M1ANDRELS 7"LNR,26#,L-80,.0383bpf,D=6.276" H 6466' DST MD TVD DEV TYPE VLV LATCH FORT DATE 6 2977 2969 16 KBG-2-LS DOME NT 20 '03/27/03 9-5/8"X 7"BKR PKR/TIEBACK,D=7.50" H 5465' e5 5449 5029 39 KBG-2-LS SO KT 16 03/27/03 4 7466 6432 42 KBG-2-LS DMY NT' 0 9-5/8"X 7"BKR URHGR D=6.18" -{ 5479' 3 8776 7378 43 KBG-2-L5 DMY M 0 2 9510 7915 43 KBG-2-LS DMY IVT 0 1 10078 8323 43 KBG-2-LS DMY IVT 0 9-5/8"CSG,47#,N-80,D=8.681" H 5663' $-5/6-MLLOLfi vNnnovv 10048' Chemical Cut,4-1/2"Tubing I 5663•-5703•(OFF w-IPSTOc ) 10124' HES 4-1/2" FBSdriIl Bilge P:ug 5Z 10104' H4-1/2"HES X NP,D=3.813" Z - 10116' H 7"X 4-1/2'BKR S-3 PKR,D=3.875' I I 10138' -14-1/2"HES X NP,D=3.813" 7"X 4-1/2"VW TIEBACK PKR W/SEAL ASSY -f 10167' I I 10159' -14-1/2"HES XN NP,D=3.725" 4-1/2"TBG, 12.6#,L80,.0152 bpf,D-3.958' H 10169' -- SCI 10171' H4-1/2"WLEG,D=3-958" 7"X 4-1/2"TIW S-6 PKR/TEBACK, D=3.850" -- 10174' ' ...1 TIW DTH LIVER HANGER,D=3-922" H 10185' 4 1 7"LNR,294,13-CR-80,_0371bpf,D=6-184" H 10386' 4 PERFORATION SUMMARY '* 10386' 4-1/2"AVA DW REIR PATCH,D=2.441" REF LOG: AVVS BHCS 07/29/96 TOTAL LENGTH=35'7" (08/17/97) ANGLE AT TOP PERF: 48©10400' Note:Refer to Production DB for historical perf data PBTD -i 12180' SIZE SW INTERVAL Opn/Sqz DATE 2" 4 10400-10410 C 08/17/97 / 2" 4 11920-11940 0 10/01/99 3-3/8" 4 11960-11970 0 03/25/97 3-3/8" 4 11970-11990 0 10/13/96 2-1/8" 4 12012-12032 0 09/29/96 _ 1-56" 4 12040-12050 S 08/01/96 7 4 12090-12110 0 10/01/99 3-3/8" 4 12125-12145 0 03/25/97 3-3/8" 4 12145-12165 0 10/13/96 4-1/2"LNR, 12.6#,13-C,.0152 bpf,D=3.958" -{ 12283' 2" 4 12140-12160 0 09/28/96 DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY LKT 11!09/77 INITIAL COMPLETION WELL: B-02A 08/19/96 SIDETRACK(B-02A) FERMI No:'1961110 09/23/09 D-16 SUSPENDED(B-02A) AR No: 50-029-20066-01 11/03/16 ALMJMD CORRECTED 10-3/4"CSG MATERIAL SEC 31,T11N,R14E 961'SNL&1598'VVEL BP Exploration(Alaska) • • TREE= "CAMN 1^E- 1 M OY B-02 Suspended ACT IATOft= BAKER KB.ELEV= 6$.68' )N 16 BF.REV= 40.57 ._ KOP= 2750' 625' 4 1/2"HES"XN"NIP,m =3.725" Max Angle= 32 79 n9 �108 � 635' 4-12"12 bq LSO xSCT W o>jsstting Datum M3= 10983' 725' TO C.,Susp.Plig Datum IVO= 8800'SS '� 800' xES 'Fasdrii'e�ge Plig TOP OF FISH 1224' "--/ 1200' Top,Cut4-1/2"Tubing 1415' JetCut,4-12"Tubng 13-3CSG,68#,K55,D=12.415' ) __ I J$' 1720' I JetCut,4 12"Tubing 2098'- 9-5/8"x 10-314"X-Over 2 Fullbore cement from Surface to 94s MD i —1300' MD in tbg, IA, and OA (10-3/4"CSG 55.56,N-80,.0925 bpf.ID-9 78" J- < --- a I 1 7'LNR 28#,L-80,.0383bpf,D=8.276" I .' ' 't'"( 9-5/8'X 7"BKR PKR/TEBACK D=7-50" Fullbore cement from —2300' 9-5/8-x r BKR LNR HGR D=6.18 �v><. M ' MD to — 2 800' MD in tbg, IA, and OA 9-5/8"CSG,47%,N-80,D=8 681' ' yL?� 10048' CheniralCut,412"Tubiig ��- 10124' HES 4-i2"'FasdriII'B�geelig 10104' --14-1/2•FES X NP,D=3.813' g I 10116• Hr X 4-1/2'BKR S-3 PKR D=3.875" ' ' 10138' H4-1/2"HtiSXNIP,D=3.813" I 7'X 4-1/2'TIW TACK PKR W/SEAL ASSY —I 10167' J _ I I`, 10168' H4-1C2-HES XN NP,ID=3.725' 4-1/2"TBG,12.86,L80,.0152 bpf,D=3.958' 10169' Fi 10171' H4-1/2'WLEG,ID=3.95$' 7'X 4-1/2'TIW S-6 PKR/TEBACK, D=3.850" — 10174' • TWW DTH LINER HANGER,D=3.922' 10185' r LNR,29#,13-CR-80,.0371bpf,D=6.184' PZ3 � 4 10,226' 11. PERFORATION SUMMARY (MD)- • 10386' —4 112•AVA OW FTR PATCH,D=2.441• FIEF LOG: AWS BHCS 07/29/9 TD TOTAL LENGTH=35'r (08/17/97) ANGLE AT TOP PERF: 48 @ 104 Note:Refer to Roduction DB for h.storic3 PBTD H 12180' SIZE SPF MB1VAL Opn/Sqz 2" 4 10400-10410 C r 4 11920-11940 0 J 3-3/r 4 11960-11970 0 3-3/8' 4 11970-11990 0 2-1/8" 4 12012-12032 0 ==— 1.56" 4 12040-12050 S 2" 4 12090-12110 0 s -- 3-3/8" 4 12125-12145 0 03/25/97 3.3/8' 4 12145-12165 0 10/13/96 14-1/2"LNR,12.60,13-C,.0152 bpf,D=3.958' —{ 12283' 2" 4 12140-12160 0 09/28/96 GATE REV BY COIVIMBITS fl OATE Fel/BY COMMENTS PF3JDHOE BAY UNIT 11/09/77 INTIAL COMPLETION WELL. B-02A 08/19/96 SIDETRACK(B-02A) FERMI'No:'1961110 09/23/09 D-16 SUSPENDS)(Et-02A) AR No: 50-029-20066-01 11/03/16 ALM JNO ACTED 10-3/4"CSG MATERIAL SEC 31,T1 it'4 R14E,961'SM-&1598'WEL BP Exploration(Alaska) 4 • • TREE= CAMERON WaL, C SOY B-02 Suspended (Contingency #2) ACTUATOR BAKB2 KB.ELEV= 66.68' BF_t3.EV= 40.57' , 1 - KOP= 2750' ( 625' I 4-1,2"HES'XN"NIP,ID =3:725' x Angle= 32 c7'10879' r I41a Datum tin= 10983' ` Cement from Surface to 1200' oatumTVD= 8800 ss —al MD in tbg, IA, and OA TOP OF FISH 1224' ' ' 1415' JetCuS4 is"Tubng 13-3/8'CSG,68#,1(55,ID=12.415 i } 1720' JetC ut,4-141"Tubiig 2098'- 19-5/8"x 10-3/4•X-over ? 6945' MD NOTE :W ELL WAS LEFT /9.8NaC1BRIIE I10-314"CSG,55.5#.N-80,.0925bpi,D=')'f" I ANNULUS AND 20BBLS DIESELF/P. it"LNR,280,1-80,.0383bpf,D=6.276' I' ,; 9.5/8"X 7"BKR PKR/TEBA ' CK,D=7.50" I � --,..-M ill,..4 12. 9-58"X 7"BKR LNR HGR,D=6.18' ' ' 9-5/8'CSG,47#,N-80,D=8.681' 10048' Chem i:a1Cut 41,5"Tubing 13124' HES 4-12"'Fasdrill'St ge Phg I I 10104' H4-1/2'HES X MRD=3.813" 1 Z 2 10116' H7'X 4-1/2'BKR S-3 PKR,D=3.875' I I 10138' H4-1/2'HES XNP,D=3.813' ' r X 4-1/7 TIWTEBACKPKRW/SEAL ASSY 1016T 1 I 10169' -4-12'HES XNNIP D-3.725' 4-1/2'TBG 12.60,L80,.0152 bpi.D=3 958' H 10169' /-4 10171' H4-1/2'WLEG,D=1958" 7'X 4-12'1TW S-6 PKR/71B3ACK, D=3.850" - 10174' 1 11W OTH LINER HANGER,D=3.922" r 7"LNR.29$.13-CR-80,.0371bpf,D=6.184" PZ3 0,226' 4-1/2"AVA DW RER2 PATCH,D=2.441" PERFORATION SUMMARY (MD)- 10386' ^TOTAL LENGTH=35'7" (0&1X97) REF LOG: AWS BRCS 07/29/9 TD ANGLE AT TOP PERF: 48 @ 1 Note:Refer to Production DB for historic PBTO H 12180' SIZE SPF I'UE RVAL ( Opn/Sgz / 2" 4 10400-10410 C 7 4 11920-11940 0 3-3/8' 4 11960-11970 0 3-3/8' 4 11970-11990 0 2-1/8" 4 12012-12032 0 1.58' 4 12040-12050 S 2' 4 12090-12110 0 • -- 3-3/8" 4 12125-12145 0 03/25/97 3-3/8' 4 12145-12165 0 10/13(96 4-12'LNR,12.84I,13-0,.0152 bpi,D=3.958' 12283' 2' 4 12140-12160 0 09/28/96 — - �- DATE REV BY COMFITS - DATE REV BY COMrU4T5 PRIDHOE BAY UNIT 11/09/77 INITIAL COMPLETION Wel: B-02A 08/19/96 SIDETRACK(B-02A) PERMIT No.'1961110 0923/09 D-16 SUSPB9IDED(8-02A) AFI N1: 50-029-20066-01 11/03/16 ALMJM]CORRECTS)10-3/4'CSG MATERIAL SEC 31,T11N,R14E,961'SNL&1598'WI t BP&ploration(Alaska) 5 • • TREE= 'CAMERON WB- E M OY B-02 Suspended (Contingency #3) ACTUA IOW BAKER KB.ELEV= 68.68' BF.ELEV= 40.57 - I KOP= 2750' ,.1 6252 TP 4-1 "HES "XN"N ,I) =3.725" M1x Angie= 32/g 10879' r = 10983' ° Cement from Surface to —725' Datum TVD= 8800'SS ►— MD in tbg, IA, and OA (TOP OF FISH}-- ;, , '; ( 1415' JetCut,4-12"Tubng mDPZl 13-3/8'CSG 68#,K55,D=12.415' 1720' JetCut,4 12"Tubing 098'— 9-5/8'x 10-3/4•X-Over 3u='q 945' MD NOTE :W ELL WAS LEFT /9.8NaC1BRINE 110-3/4-CSG,55.5*,N-80„0925bpf,ID=9.76' - 14 ANNULUS AND 2OBBLS DIESEL F/P. 7'LP42.264/,L-80,.0383bpf,D ” NI =6.278' i I`*`"' 9.5/8'X r BKR R(R/TtB3ACK,D=7.50' a CI k 9-5/8'X r BKR LNR HGR,D=6.18- 9-5/8"CSG,47*,N-80,13=8.681' .18"95/8`CSG,47>Y,N80,D=8.881' 111 , , 10048' Chem i:a1Cut 4-1/2"Tubng - - - �— 10124' HES 4-12"'Fasdrill'Bri9ge Phg I I 10104' H4-1/7HES X MP,D=3.813' 1 C. Z—I 10116' H7'X 4-1/2'BKR S-3 PKR,D=3.875' I I 10138' H4-1/2'HES XNP,D=3.813' I 7'X4-1/7TIWT163ACKFKRW/SEAL ASSY H 1016T I I I 10169' —4-1/2'HES XNNP,D=3.725' 4-1/7 TBG,12.68,L80,.0152 bpf,D=3.958' H 10169' 10171' —14-1/2'WLEG,D=3.958' T X 4-lir TNN S-6 F(R/MHBACK, D=3.850' H 10174' J co l TNN 13TH LI ER HANG6,D=3.922' I-- 0185' I 7'LNR,29*,13-CR-80,.0371bpf,D=6.184' PZ3 k 10,226' 4-1/2'AVA OW RETR PATCH,ID=2.441' FEF FORAT ON SUMMARY (MD)- 10386' —TOTAL LENGTH=35'T (08117!97) REF LOG: AWS BHCS 07/29/9 TD ANGLE ATTOPFEW 48 ? 104 Note:Refer to Roduction OB for histonc2 POTD H 12180, SIZE SPF INTERVAL Opn/Sqz 7 4 10400-10410 C % J 2' 4 11920-11940 0 / 3-3/8' 4 11960-11970 0 3-3/8' 4 11970-11990 0 2-1/8' 4 12012-12032 0 1.56' 4 12040-12050 S " 2" 4 12090-12110 0 r"uruti 3-3/8" 4 12125-12145 0 03/25/97 3-3/8' 4 12145-12165 0 10/13/96 (4-1/2'LMR,12.8*,13-0,.0152 bpf,D=3.958' — 12263' 2" 4 12140-12160 0 09/28/96 DATE FiEV BY COASAENTS DATE RE/BY COM.B'IIS D UE BAY UNIT 11/09/77 INITIAL COMPLETION WELL: B-02A 08/19196 SIDETRACK(B-02A) PERMIT No:1961110 09/23/09 D-16 SUSPENDED(B-02A) AR No: 50-029-20066-01 11/03/16 ALMUI 1D CORRECTED 10-3/4"CSG MATERIAL SEC 31,T1114,R14E,961'SN_.&1598'WEL BP Exploration(Alaska) 6 • 0 Loepp, Victoria T (DOA) From: Worthington,Aras J <Aras.Worthington@bp.com> Sent: Monday,June 04, 2018 1:30 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU B-02A(PTD 196-111, Sundry 318-199) Suspend Hi Victoria, Although I did not include that step explicitly in the procedure,we will definitely do some kind of pressure test/injectivity test before we pump cement so that we can plan the job out appropriately(plan for losses and/or plan for pumping the job Fullbore if CT cannot re-enter the tubing stub). There was a pressure test on the lower bridge plugs performed before the rig left the well in 2009, however the bridg plugs are composite bridge plugs which usually don't have a guarantee of pressure integrity beyond a few weeks or months due to the possibility of the composite material degrading in high-temperature/hydrocarbon environments. o we won't know the status of these plugs until we pressure test/injectivity test once we get through the upper composite bridge plug. Also,on a separate note,could you let us know a time that we could come into your office and meet with you and yo r staff to discuss a Sundry proposal for a well? We would like to discuss it with you all before we submit the Sundry to et your feedback and/or prepare to answer any questions you may have. Thank you, Aras Worthington Well Interventions& Integrity Engineer 1 BP Alaska Inc. Office: (907) 564-4102 Cell: (907)440-7692 From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday,June 4,2018 10:59 AM To:Worthington,Aras J <Aras.Worthington@bp.com> Subject: PBU B-02A(PTD 196-111,Sundry 318-199)Suspend Aras, In your proposed procedure, after milling through the 9-5/8" CBP,would it be worth while to see if there's any pressure from below or to pressure test? Is there reservoir isolation with the bridge plugs at 10124' MD?Was a pressure test performed when the plugs were set? Victoria Victoria Loepp Senior Petroleum Engineer • State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppalaska.gov 1 STATE OF ALASKA 1 f,.J 1, 3 •1 2015 • ALASKA OIL AND GAS CONSERVATION COMMISN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed AOGC Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspend Well 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 196-111 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20066-01-00 7. Property Designation(Lease Number): ADL 0028310 8. Well Name and Number: PBU B-02A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12283 feet Plugs measured 800 feet true vertical 9075 feet Junk measured 1224 feet Effective Depth: measured 725 feet Packer measured See Attachment feet true vertical 725 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 30-110 30-110 1530 520 Surface Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 4920 7"29#L-80 5465-10385 5042-8613 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26-10171 26-8460 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: S(ANN N O V 1 2 2& 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 998 19547 528 0 519 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 11 Gas 0 WDSPL 0 if Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP EV SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 4."-i,_ C .t -, Phone +1 907 564 4424 Date 7/31/15 Form 10-404 Revised 5/2015 V T L 9 fl?'. 9_/YI Submit Original Only A Qrinnec JVk Aim 1 L 1111c • a, • U CL o � Q o a`) 'i >+ Y e = a) as i p CO c0 m ++ CV N N r r r V 0 co Co 0 co CO u m • CO -a a co co L p � r-- Y . rr r r CO a d W W W O. • Q Q Q aaa m E < < < Z o 0 0 mmm • • Q 0 0 0 0 0 0 Cp000CD0) CDN0 I•- N M N- O If) 0 V- N 01 Tr Ns N- C) +L M O� CD N M NO COD C) U) 00 O Tr 00 c- m CO CC) V CD 00 00 00001OO MO CO N 00 O) '- CD O) M M e- ONI- r- N Ul 00 00 a 00 O N O CO 00 CO 00 CO C'r) N N O) C') O N y- N CD a, O 00 Cn O 07 BT.:T- CD Nr C') CO T- O) up 01 CO M T- T- _ N CC) O O V 1 1 I I I a a N 00 OCOCOCOaOODC�000 Ch OI 07 N N CA N Nt N AftM 0 CD 03 Cip NL 00C) mr CD J vk J CD CU4t Cc) 4,k J CSO NU1 ,00u -I. 01 y- y- a 0) 4 CAO 00 N J O T N Ch W W W W F- F- F- NUowoo 2222 0 C) OCLcfQQZ Z W W W W W 00 OHF F- HZD U Z Z Z Z J • • a) as m �nf� � � `ctaovrnNNN (0 M 0) 0) CO I, LO CO 0 OtoOcMOcMcoofOcMin a, M 0) 0 O r N N M CO CO 0 0 x 0 0 0 0 0 0 0 0 0 a O c') lc) O) N U) M 0) N N « ti 0) I'sO N M t (0 CO a M w o o N- N O CO O) o C'') 0 p cCoococo ) 0) ) rnrnrnrn 0 w w 0 re z w w 0 0w w0 gg w UJ OO 0 0 W YY g 0 0 0 0 No 0 0 � O J U U W w +' a I� O) M lc) r d' e' CO CO J J J Q f/) C D 0 '- ' N N N N CN N U U U J w J D R Q Q Q O 0 0 °' w 0 0 0 W Z O 0 L w w w a 1 Q Q 0 < 2220cncn cncn N Q0 a o = Z OOOoN00to0 (0o O a) NI- O 0 O) O Co O • CD 0 o ' r N N N N N N N cvay a) 1- 2 - 1-J = O a J a ` � � 20cncn (ncna) d CL O U a, 0:103mm030303mm0303 a 0 t d a R co CO CO CO CD CD CO CO CO CO CO 0 0 0 Co 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 0 w O N N N N N N N N N N N Z Q w 0 Ce L. N N N N N N N N N N N Z d W J O W Da0) coa) 0) a) 0) a) wa) 0) 0) Qm 00 j w J J -' p LU LIJ LU Q Q a cn LL LT. IQi cn a re E m Z Q Q Q Q Q Q Q Q Q Q < ?� N N N N N N N N N N CV cn o 0 0 0 0 0 0 0 0 0 o m a a a 0 J cwt a w a m CO CO m 03 CO 03 6 6 03 00 Q Q CO m u_ LL co co a ce • • if o L- m „,a) LL r D a) 0 c) _ C Q o U >' a) O 0_W C U O >- = ^2 c0 .. N c E L a5o Eaa �C. co ~ -ON = U � 5 = 0- a) 1515 9 m cg m 0 w v) o ii O -0 pfd O 0 Oa c '_ 0 CD o_o °' Q � � O c\ 0 A 0 D O .� 0 LO CCD Q O O co E OU -oa = O .cn a) > a Ocaa) Cfl O o c O 5 Oc . a ti Ho3c>i) z w I— < cn a H N o 70 0 N m P toU Q • • Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT B-02A Field/Pool: PRUDHOE BAY/PRUDHOE OIL Permit#(PTD): 1961110 API Number: 50-029-20066-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 3/1/2010 Surface Location: Section: 31 Twsp: 11N Range: 14E Nearest active pad or road: B-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,clean Pad or location surface: Dry, flat gravel Location cleanup needed: Clean Pits condition: Filled with Water Surrounding area condition: Clean Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: No Access road condition: Clean Photographs taken(#and description): 3: Wellhouse front,Wellhouse back, Pit Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings,where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description, condition: McEvoy WH, Dry Hole Tree, Gauges(operational). Valves are in good working condition. Cellar description, condition,fluids: Clean water in cellar with no sheen Rat Hole: N/A Wellhouse or protective barriers: Wellhouse Well identification sign: Attached to wellhouse Tubing Pressure(or casing if no tubing): 750 psi Annulus pressures: IA= 500 psi, OA=350 psi, OOA= 150 psi, 000A= 150 psi Wellhead Photos taken (#and description): 4:Wellhead/Tree, Wellhead left, Wellhead right, Tree Work Required: None j�! t Operator Rep(name and signature): Kevin Parks PaL7 AOGCC Inspector: Bob Noble Other Observers: Matthew Do Inspection Date: 6/28/2015 AOGCC Notice Date: 6/26/2015 Time of arrival: 1:30 PM Time of Departure: 1:50 PM Site access method: Truck • • • '0 E as yo 0 L J O C to - - Cl) NJ vi • n�c1n� "' - - 7 J _ c J E E1 ' IIII1 _c COM TO O .e (n o CO 4 -r N 0 0 0 o Q r c o w N f,: 0 4,-.: i C1 VI r, ,a O ' Q Y p a O m A I o a M < O a F4 G) ER a a n ^ O M O � 0 , am ti N. 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''t' ''' ' '' ;" _ , , , . . } . ,....,...: ,Y .,. :, t { s ky � ., ' �11 �o- r ,\:, ,,,.,, ,,, n. .,,,,,,, ,,,, , ,, , ;t: ' .,:..,',"1:',''.1,, " } i r ry . vim'w ii, , , i,, .„,,,,,..,.., !ti*'. ': ,,, '60 a p f .,., .,,, ,,,,. , ' '—,. ' - :t,, , „ s .,`°'• ( y{: .'` . .2„,-,,,,.-:,,,,..4.,..,,,,i. ,. • 't, ._.' `' - ,x �«.. ... +M. .,- a „IE.a,� ampp"yn� ka g.3 y, �.yam a � ..U ,." mk "mu*s is f it i tg 't 3�it�y 'p� r Ory '` s j ? :- - \ h. 0 . 1-: d ..,/,._. yy 1 w , ....-.. .4-;:f.;.;,---- _,. , as ' • +�n� .t W. k***lit: .,''''''''*',.. 1''''M.'-'' ' ... ,ni ,'[\,. ry t'' ti r , '-...,: .'.,_. 1 . tt . jjj ir ,,'4f,..,„ •', , .. t .,,.; ‘......,,. - .1.,,, :,..,,'''.. ',„ ' '44kiNii --,------,:i...t.',..Z.L**'''''''''; `,71 in \ 441414,,, ,,,,,,"i.''''.., '1'''',„ '*''''..''....,,;,%.. "\- 4„.i.:7,,.*: --` ,:,, ' \ 4,sti\k‘ 4‘,',4k,lSe\ -"--- ------ 4''''''' . • c ..:,,,,,,..,..4., ,,...‘ . „:,,,,,...,-.., .,,_.,,..„. \ , t � � 1ti %? a i **::i.:: '-'-:;;?.v;41:24- :/2„.4'i-if ��.'.'^'- 6 3 ct. � �; < r' � t l .4‘;‘,1,...., - ir.,.;,-„,: „.',,,,,i; ...„:;".;-.*.; ',:,,',,,,,,',..,..' \ . itt x? ,7,,.-",--„',.:, , . cift.--‘1;,.2.. ..!,, 7..,,,, '''' . ' .,kk' 1 % , , ,, , ,C .4kSil4t 0...,, ,,, , ',It,,,,,,,,, ,",.t.:\::::4,,,,,,::', .,k,,,,:',,,,t,,.:.,,N, ,. , %.,,,',\,.., -,,, k,.,,,...'„..,it.,4\4\ -k\ TREE= 'CAMERON1111 III V LHFAD= MCEVOY B -0 2A ACTUATOR= BAKER KB.a.EV= 68.68' SUSPENDED 09/23/b6 -DO YON 16 BF.BEV= 40.57' KOP= 2750' I J 625' 4 1/2"HES "XN"NIP,ID =3.725" Max Angle= 32©10879' 636' 4-1/2°12.6#L-80NSCTWo±st ig Datum MD= 10983' Datum-ND= 8800'SS 725' susp.P q r _ 800' HES 'Fasdrill'Bilge Phg TOP OF FISH —f 1224' Foi`X. .*:4:4! 1200' Top,Cut4-1/2"Tubing : : : .W.W:� JetCut,4-1 g >�• •rr,r, 1415' /2"Tuba 13-3/8"CSG,68#,K55,D=12.415" --f 4545' — 1720' JetCut,4-1/2"Tubhng 19=5/8"x 10-3/4"X-Over ,_1968' J 10-3/4"CSG,55.50,K-55,.0925 bpf,D=9.76" H 2380' NOTE :W ELL W AS LEFT W /9.8 N aC 1B R]N E ]N ANNULUS AND 2OBBLS DIESEL F/P. A 7'LW,260,L-80,.0383bpf,D=6.276' H 5466' ` 9-5/8"X 7"BKR PKR/TRACK,D=7.50' —{ 5465' 9-5/8'X 7"BKR LNR HGR,D=6.18" —{ 5479' a 9-5/8"CSG,47#,N-80,D=8.681" --f 5663' ' , 10048' Chem ralCut,4-1/2"Tubing 10124' HES 4-1/2"'Fasdrill'Br ge Plig >< _ 10104' H4-112"HES X MP D=3.813" g M4 10115' 1—7"X 4-112'BKR S-3 PKR,D=3.875' I I 10138' H4-112"t 5X NP,D=3.813" 7"X 4-1/2"TM/TEBACK PKR W/SEAL ASSY H 10167` I ' ' 10159' H4-1/2"HES XN MP,D=3.725" 4-1/2"TBG, 12.6#,L80,.0152 bpf,D=3.958" —{ 10169'_ 010171' —14-1/2"1/VLEG,D=3.958" 7'X 4-1/2"TIW S-6 PKR/TEBACK, D=3.850" —i 10174' I 0 TW 0TH LNER HA NGB2,D=3.922" H 10185' 7"L112,290,13-CR-80,.0371bpf,D=6.184" 10386' PERFORATION SUNIVARY S 10 H4-1/2"AVA DW -!RETR PAT ,D=2.441" REF LOG: AWS BHCS 07/29/96 TOTAL LENGTH=35'7" (08/17!97) ANGLE AT TOP PERF: 48 @ 10400' Note:Refer to Roduction DB for historical perf data PSTD J 12180' SIZE SPF NTERVAL Opn/Sqz DATE I 2" 4 10400-10410 C 08/17/97 % / 2" 4 11920-11940 0 10/01/99 3-3/8" 4 11960-11970 0 03/25/97 3-3/8" 4 11970 11990 0 10/13/96 2-1/8" 4 12012-12032 0 09/29196 1.56' 4 12040-12050 S 08/01/96 2" 4 12090-12110 0 10/01/99 3-3/8" 4 12125-12145 0 03/25/97 3-3/8" 4 12145-12165 0 10/13/96 4-1/2"LNR, 12.6#,13-C,.0152 bpf,D=3.958' H 12283' 2" 4 12140-12160 0 09/28/96 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/09/77 IMTTAL COMPLETION WEL: B-02A 08/19/96 SIDETRACK(B-02A) PERMT No: 1961110 109/23/09 D-16 SUSPE )(B-02A) API No: 50-029-20066-01 SEC 31,T11N,R14E,961'SNL&1598'Wa_ BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/28/15 Inspector: Bob Noble Operator: BPXA Well Name: PBU B-02A Oper.Rep: Matt Do PTD No.: 196-111 Oper.Phone: 659-5102 Location Verified? Yes Oper.Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 03/01/10 Date AOGCC Notified: 06/26/15 Sundry No.: 310-027 Type of Inspection: Subsequent - Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 750 Photos Taken? Yes IA 500 OA 350 SCANNED AUG 1 4 2015 Condition of Wellhead: OOA=150,000A=150,Location was verified with a pad map.No lines attached to wellhead.All Lines blinded with gauges.The condition of the wellhead looked good with no signs of leaks or drips.Cellar looked to have clean H2O with no sheen. Condition of Surrounding Surface ' Location: Wellhead was procted with a wellhouse that looked to be in good condition.Good clean gravel around wellhouse. Follow Up Actions " Needed: none Comments: none Attachments: Photos(3) - REVIEWED BY: Insp.Supry �J( Z 7/111S" Comm PLB 12/2014 2015-0628_Suspend_PBU_B-02A_bn.xlsx a .:? .1 '413i OD a W W 4 Q d m R i g Z z J J a Y s 5igi gailg k N a ,. A 4 CO a i as 0 o U 9 COGJ tz. 01I -_ - U __ ate..,i TO 0 a ¢� •0 V0 az� 00 4.41 cu °` o o vnaa � 0a; if/ if4ii ,,,,,..„ _ MILI _ , y 11111111111.1 It ii • 4 t, 01 1.4 a 0. arif :1: 'fit ! f r r . ( r 14 • x .r JP SCC / 1f • tit 4 . . „. .,.. .... , , , ir,////d 7 , , - Jr- -,. - , , t , ..... o ,,, , I, : ,,,,, . . , - / ,,,,, . :,,, .. .. ... _. 1, isp 1 o It /7//, # -,' 1 ill /11' et Ii Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by; Bevedy~Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other 0 Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ INSPECT Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ WELL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to DrilLNumber: Name: Development ^ Exploratory ^ ~ 196-1110 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-20066-01-00 8. Property Designation (Lease Number) : ,~ 9. Well Name and Number: ADLO-028310 PBU B-02A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 12283 feet Plugs (measured) 725' TOC feet 800' 10124' true vertical 9075.28 feet Junk (measured) 1224' feet Effective Depth measured 725 feet Packer (measured) 10115 true vertical 725 feet (true vertical) 8420 Casing Length Size MD TVD Burst Collapse Structural Conductor SEE ATTACHED Surface Intermediate :« '~^",~r,;t _ ~f f Production Liner Liner Perforation depth: Measured depth: SEE ATTACHED - - - _ - True Vertical depth: _ _ - - - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# LL-80 22 - 10171 22 -8460 4-1/2" AVA DW RETR PATCH 10386 - 10422 8614 - 8639 Packers and SSSV (type, measured and true vertical depth) 7" X4-1/2" BKR S-3 PKR 10115 8420 ,~~~ ~.~ ^"~~ 12. Stimulation or cement squeeze summary: F - s ~~ ~~'" ~ ~ ~~ Intervals treated (measured): ~ Treatment descriptions inGuding volumes used and final pressure: ~ <;jt;lE ~t`~x~l~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: ~ Copies of Logs and Surveys Run Exploratory^ '~ D elopment ^~ Service ^ Daily Report of Well Operations X 16. Well Status after we SUSPENDED Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Prebie Printed Name Gary Pr ble Title Data Management Engineer Signature UG ~ 5 2010 Phone 564-4944 Date ~ Jj~ ~'~ l0 Z /~ ' ~ • WELL NAME: B-02A 23, Attachment - Castn Uner and fementin Record Casing f)ep~tr~ n-rvD Hole Size Wt. Per Ft. Grade To ottom Top Bottom Size Cementing Record 3t?" Stave Pi Surface 107' Surface 107' 38" 150 sx Perrr~frost 20" 94# / 133N l{-40 / K-55 Sut#ace 2308` Surface 2308' 26' 5100 sx Permafr~t 1 f3" 85S H-40 / K-65 Surface 2192' Surt~e 2192' WA Circulati ,Not Cemented 13.3!8' Bt#/ 68# H-40 / K-55 Sudace 4545' Surface 4323' 17-112' 1200 sx Class'G' 9-5/8' 47# L-80 Surface 1968` Surface 1986' 12-i/4" 3530 sx Ciass'G' i0-3/4' 55.56 K-55 1968' 2380' 1988' 2380' 12.1/4' 9-5/6' 47# N-80 2380' 5883' 2380' S18B' 12-1/4" 7" 291E 13Cr / L-80 5465' 10385' 5042' 8613' 8-11"L" 225 sx Class 'G• 4-1/2" 12.6# 13Cr 10187' 12283' 8458' 9075' 6" 86 sx Glass'G',166 sx Class'G' B-02A 196-111 PERF ATTOC:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base B-02A 8/6/96 PER 12,040. 12,050. 9,012.25 9,013.88 B-02A 8/7/96 PER 10,400. 10,410. 8,623.73 8,630.55 B-02A 8/13/96 S4Z 10,400. 10,410. 8,623.73 8,630.55 B-02A 8/13/96 SQZ 12,040. 12,050. 9,012.25 9,013.88 B-02A 9/14/96 SQZ 10,400. 12,050. 8,623.73 9,013.88 B-02A 9/28/96 PER 12,012. 12,032. 9,007.62 9,010.94 B-02A 9/28/96 PER 12,140. 12,160. 9,029.49 9,033.82 B-02A 10/13/96 APF 12,145. 12,165. 9,030.52 9,035.02 B-02A 10/13/96 RPF 12,012. 12,032. 9,007.62 9,010.94 B-02A 10/13/96 APF 11,970. 11,990. 9,000.5 9,003.91 B-02A 3/25/97 APF 11,960. 11,970. 8,998.79 9,000.5 B-02A 3/25/97 RPF 12,125. 12,145. 9,026.53 9,030.52 B-02A 3129/97 BPS 10,400. 10,410. 8,623.73 8,630.55 B-02A 10/1/99 APF 11,920. 11,940. 8,991.95 8,995.37 B-02A 10/1/99 APF 12,090. 12,110. 9,020.3 9,023.74 B-02A 8/22/06 BPS 10,124. 10,400. 8,426.28 8,623.73 B-02A 9/23/06 BPS 800. 802. 800. 802. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • Prudhoe Bay Unit Well B-02A, PTD 1961110 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU B-02A on 7/28/10. 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 Chuck Scheve witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one-quarter mile radius of the surFace location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU B-02A was suspended on 03/01/10./ • PBU B-02A is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with a bridge plug in the tubing at 10124 and a bridge plug at 800 ft, with 75' of cement on top. • The well is mechanically sound as proven by a pressure test after the plug was set. MLB 08/23/10 • Suspended Well Site Inspection Form Notify AOGCC Inspecfors at least 10 days prior to inspection to allow witness Weil Name: PRUDHOE BAY UNIT B-02A Fieldll'ooi: Permit # {PTD): 1961110 API Number: Operator: BP EXPLORATION (ALASKA) INC Date Suspended Surface Location: Section: 31 Twsp: 11 N Range: Nearest active pad or road: Prudhoe Bay B Pad Take to Location Digifal camera i3rief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools PRUDHOE BAY / PRUDI-IOE OIL 5002920660100 14E 3/1/2010 Map showing well iocation /Aer-iai photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or• near pad Condition of Surface Location AOGCC requires: 1 } a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2} photographs showing the condition of the iocation surrounding the well General location ca~dition: Good Pad or~ iocation surface: Dry Location cleanup needed: No Pits condition: Clean Surrounding area condition: Clean Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: None Samples taken: No Access road condition: Good Photographs taken {# and description}: 4: wellhouse, sign, and pits Condition o€ Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing ttre wellhead condition Wellhead/tree/valve description, condition: McEvoy dryhole tree w/ McEvoy wellhead. All equipment in good condition Cellar description, condition, fluids: Clear fluid in gravel cellar _ Rat Hole: Mouse hole at 3 o'clock Wellhouse ar protective barriers: Wellhause Well idenfification sign: Yes Tubing Pressure (or casing if no tubing}: Vac Annulus pressures: IA: 0 OA: 200 OOA: 100 OOOA: 100 Wellhead Photos taken (# and description): 5: tree, cellar, and risers Work Required: None Operator Rep (name and signature): Jerry Murphy -;'"-'<<~ry~ •~.~,-~;;4.;,,,~,:~~.~' :~,;,; -~ °~~,=-k~ AOGCC Inspector: Chuck Scheve Other Observers: ~f Ryan Holt Inspection Date: 7/2F3/2010 AOGCC Notice Date: 7/27/2010 Time of arrival; 11:15 AM Time of Departure: 11:30 AM Site access method: Access road TREE= 7-1116" CAMERON WELLHEAO= MCEVOY ACTUATOR= BAKER KB_ ELEV = 68.68' BF. ELEV = 40.57' KOP = 2750' Max Angle = ,mm 82 ~ 10879' Datum MD - _ 10983' Datum TV D = 88~' SS • B-02A FROM DRLG -DRAFT SUSPENDED 09/23/06 - DOYON 16 OF FLSH H 1224' 13-318" CSG, 68#, K55, iD = 12.415" 4545' 9-5/8" x 10-3/4" X-Over 196$' 10-314" CSG, 55.5#, K-55, .0925 bpf, ID = 9.76" 2380' LNR, 26#, L-80, .0383bpf, ~ = 6.276" 9-518" X 7" BKR PKR i TEBA CK, ~ = 7.50" 9-5/8" X 7" BKR LNR HGR, ~ = 6.18" 9-518" CSG, 47#, N-80, ~ = 8.681" I 5465' F I 5479' I 1 5653' I 625' 4-1/2" HES "XN" NIP, ID = 3.725" 636' 4-1 /2" 12.6# L-80 NSCT Workstring 725' Plug / Susp T O C . . . . , 800' HES `Fasdrill' Bridge Plug 1200' Top, Cut 4-1/2" Tubing 1415' Jet Cut, 4-1 /2" Tubing _ 1720' Jet Cut, 4-1l2" Tubing NOTE :WELL WAS LEFT W/ 9.8 NaCI BRINE IN ANNULUS AND 2066LS DIESEL F/P. 10048' Chemical Cut, 4-1 /2" Tubing / - - - 10124' HES 4-1 /2" `Fasdrill' Bridge Plug /~ 10104' 1--14112" HES X N~', Q = 3.813" ~ 10115' H 7" X 4112" BKR S-3 PKR, ID = 3. 1 7" X 4112" 71WTEBACK PKR WI SEAL ASSY 41/2" TBG, 12.6#, L80, .0152 bpf, ~ = 3.958" 1 1o1s7' I 7" X 4112" TNV S-6 PKR/T~BACK, ~ = 3,850" ~--~ 10174• TMV DTH LINER HANGER, ~ = 3.922` 10185' 29#, 13-CR-80, .0371 bpf, ~ = 6.184 I'-1 103$5 PERFORATION SUMMARY REF LOG: AWS BRCS 07129/96 A NGLE AT TOP PERF: 48 ~ 10400' Note:. Refer to Production OB for histor~al perf data SIZE SPF ad'TERNAL OpnlSgz DATE 2" 4 10400 - 10410 C 08!17!97 2" 4 11920 - 11940 O 10!01 /99 3-318" 4 11960 - 11970 O 03/25/97 3-318" 4 11970 - 11990 O 10!13!96 2-1 /8" 4 12012 - 12032 O 09129/96 1.56" 4 12040 - 12050 S 08/01/96 2" 4 12090- 12110 O 10/01!99 3-318" 4 12125 - 12145 O 03/25/97 3-318 4 12145 - 12165 O 10!13/96 2" 4 12140 - 12160 O 09/28/96 10138' 4112" HES X N~, D = 3,813" 10159' 41/2" HES XN N~, ID = 3.725" 10171' 41/2" WLEG, ID= 3.958" 1~6. 41Y2" AVA OW RETR, PATCH, ~_ TOTA L LENGTH = 35' 7" (08/17!97 I PBTD I 12180' 1 41 f2" LNR, 12.611, 1S-C,.Oi 52 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMEMS 11!09177 ORIGMIAL COMPLETION 08111!06 MMVS PROPOSED RWO 08119!98 RIG S~ETRACK 09/27/06 pag SUSPENDED CORRECTIONS 07104!01 CH/KAK CORRECTIONS 06/07102 RLftgi GLV UPDATE 03121/03 JDW/KK PERF CORRECTIONS 03!28103 JCM/TLH GLV UPDATE PRUDHOE 8AY UNfT WELL' B-02A PERMIT No:'1961110 API No: 50-029-20066-01 SEC 31, T11 N, R14E, 961' SNL 8 1598' WEL BP Exploration (Alaska/ • • 1088' - Enter/Exi I ~~ ~ 7 ~ 57 ('~ Enter/Exit ~ Enter/Exit ~~ J ~~ 1 o M 2 / ~ X F 9 5 ~~ 52A 18 ~ 8 ' ~g ~ 28 19 3 '- 27 36 ~0 ~ ~ , ~'`~ 30 6 21 4 22 5 23 33 2 24 1 25 O 34 r ~ ~ 26 ~ N 17 ,~ ~1s 15 14 ~ ~ i CAD - I ctF ; 13 _,1 12 ~ _, Q ~, 35 0 ~_~ 11 ° r~ 31 1 32 ~ ~ i ~ ~~~ ~ ~ 520' 0 z ~ Enter/Exit WELL PRODUCER ^ or WELL INJECTOR ~ DATE :01/06/2009 SCALE : 1" = 300' MAP DATE :2007 PBU - B PAD WELL SLOT W/CONDUCTOR J bs14495.dgn I t i ! ~'' s , -''i2µ4 ~ r ~.~ ~~ ~ ,,~ r" ,. _ ~ p, rte ,, , '~ -'~ ;~-~._~ .+r.a ~_ ~, ~ .f. i ~. ~. ..., ~ ~ ,~ '~; , .~ ;~_ ,~.. ~ ~ r ~' ~' 1 ~~, s • • • • ~~~ ~~a~~~ ~r 1 s ~~ ~,. .` ~ x ~`~ ~: .-~ i ` ~~ . ~~<~ ; y , ~~.' ~ t~ ~ ,' d 4 ~, i + f r yb~1 ~- I t } ~ 5~~ I ~" ~ 4 ~s tt vF,. ~ a Y'~~a ,~ ~ ~ ~Y~t}}g. s ~~t$~1 5a-4 ~~ f t '.~ AA ~ ~i i dTf ~ { I ~ 2 it r ~ r «r G:>; K.. F V ~ I~~~ !~+ 5 Vl'. ', ~ n~ ~ ' ~ F ~ [>,j Y~ V t f Y M x a ~ '~' ~ - ~;~~;r `~ ~~ °~ pbn . t ~ i~ ~' y RR ~, ! 1'Fl ~ k ~ayc ~ T ~, 0.t„ .: ~,~ a r :~ v ~ ,{f M i ~w ~ ~,~~y~ ~ a, ~ ~s ~~ ~ ~ ,,?I ~H t ~"llk t7'~'~~~~ } ~ ~ ~~ ~ ~. ~ ~\ ~ ~t~r + yt'.,S ra ~ s,~; d Gay.' .~ s„ ~ '~.> at l • • sTAT~ ©~ A>_AS ~n, MAR ~ 0 ' 201D ALASKA 41~ ANC? GA5 CONSERVATION CflMMtSSIC}N ~~. WELL GQMPLETiON CJR REeQNiP~ET1C?N REPORT AND LC~G 1a. Well Status: ^ OII ~ Gas (~{ SPIUC ~ Other ~ Abandoned ~ Suspended 20AAC 25.105 20AAC 25.114 I~ GINJ Cl WiNJ ©WAG Q WDSPL ^ Other No. of Completions Zero 1b. Well Class; ~ ~@velopment ~ EXploratOry d Service L~ Strat~raphic 2. Operator Name; BP Exploration {Alaska} inc. 5. mate Camp., Susp., arAband.: 31112010 12. Permit to DriltNumber. 196-111 310-427 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-651.2 6, Date Spudded: 07113/1996 13. API Number: 54-029-20466-01-40 4a, location Of Weli {Governmental Sections: Surface: 1598` F EL SEC 951' FNL 31 T11 N R14E UM 7, Date TA, Reached: 07/26/1996 14. West Name and Number: PBt.i ~-02>4 , , . , , , Top ofProduc[ive Horizon: 12$2' FNI, 3174' FWI, SEC. 32, T11N, R14E, l1M g, ~ ~~ above MSL}:. 68,5' Gtr (ft above MSL}: 15. Field I Pool(s): [?rudhoe Say Field 1 Prudhe~e Bay rotas Depth: 1790' FNL, 4912` FWL, SAC. 32, T11N, R14E, UM 9. Plug Bads Depth {MD+T3/D): 725' 725' Oil Poai 4b. lacafon of Weii (State Eiase Plane Coordinates, NAD 27}; Surface: x- 664041 y_ 5949689 Zone- ASP4 10, Totai [?epih (MO+TVD}: 12283' 9075` 16, Prope-'tY Designation: ADL 428310 TPI: x 668820 y- 5949474 Zone- ASP4 -_--_- Total Depth: x- 670371 Y- 5949005 Zone- gSPq 11. SSSV Depth (MD+TVD): None 17. teandUse Permit: 18. Directiana! Survey: ^ Yes ~ No Subrrtit electronic and tinted information er 20 AAG 25.05© 19. Waterdepth, if offshore; N1A ft MSL 20. Ttrickr~ss of Permafrost {TVOj: 1940' {Appt`Ox.} 21. logs Obtained {List all logs here and submit electronic and printed information per 20 AAC 25.071}: MWD, CBL, GR, CCL, SBT, DiR-GR, L71FL, SP, TEMP, BFtC-ACOUSTIC LOG, CN, Z~L 22, Re-OrilUlateral Top Widow MD1iVD: 5663' 51'96'. 23. GASlNG, IiNER AN0 CEMENTING RECQRD SErrirtc [ }EPrEt Mo SETTING DEPTH Tvo HOLE Auourrr CASING Wr. PEIt FT. GRADE TOP BOTTOM TOP BOTTOM SIZF. CEMENTING fIECOt2D Putt `~~P Atfa i~ 24. Open to prodactian or injection? Cl Yes ~ No 25. TUBING RscoRa If Yes, list each interval Open (MD+TVD of Top & Bottom; Perforation Sue and Number}: SIZE DEPTH SET MO PACKER Sr"r ti+o 1 ~n+o 4-112", 12.61#, L-80 1fl171' 10115'/ 8420' MD Tva MD TVD i~ ° ' ~' ^ ~~ 2ti. ACID, FRACTURE, CEMENT SQUEEZE, ETC: ry ~y . t ?~ ~ ~y ~~~ ~' ~ultd ~ ~ DEPTH INTERVAL(MD) AMOUNT AND KIND OFM~TERIAIUSEd 12040' -12050` & Cmt Sqz to finish cmt job for 4-112" Liner, 3S Bbts 10400' -10410' 'G' S z_d at 4Q00 spi; 16 Bbls 'G', Sqzd at 30p0 psi 804' Set Fasdrill Bridge Plu 725' Set Dement Plug w~6 BbisArcticset 27. PRODUCTION TEST Date f=irst Production: Not on Producfion Method of Operation (Flowing, Gas lift, etc.): N1A Date Of lest: Flours Tested: Production For Test Period OIL-BBL: GAS-MGi`: WATER-BBL: CNOK~~ SIZE: Gas-OIL RATio; s=low Tubing Press. Casing Press: Calculated 24-Hour Rate .~ {}~c-Bst.: t~AS-Mcr:: iNaTeR-E3r+~: Qu GRavt'rv-API {eoRR): 28. GORE DATA Conventi onal Core{s} Acqui red? (,~ Yes ®Nn Sidewall Core(s) Acquired? ^ Yes ~ No If Yes to either question, list formatans and intervals cored (MOtTVD of top and bottom of each), and sumrnarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed}, Submit detailed descriptions, core chips, photographs and laboratory analytical results per 2Q AAC 25Q.0T1. None corm ~V-atrf Kevrseo ~rueur~~UM~ M~, ~ ~ q~~ iNUEO ON REVERSE Submit/original C?Aiy • 29. GEOLOGIG MAf2KERS {List all fomtatians and markers encounteredj: 30. FORMATION TESTS NAMiE Mt) TVE3 Well l"ested? ^ Yes ®No PennofrostTop if yes, list intervals and formations fasted, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Bass detailed test infomtatian per 20 AAG 25.071. Sag River ~ 10226' ahr~t~(ik ~ 1tF2$$` Sadierochit ~ 90386' ~ Zone 4A ~ 90556' Zone 3 ~ 109Q0' Formation at Total Depth (Name):. 8500" None 8531' 8613' 8721" 882g` 39. List of Attachments: Casing & Liner Summary, Weil Scherriatic Diagram 32. t hereby certify that the foregoing is true correct to the best of my knowledge, Signed: AI Schmoyer r L~ {~'Z=,~..~ Title: Sr. Pad EngineeP Date: ~~~~~ ~ `'' PBi.I t3-02A 196-111 31 i~-t727 Prepared By NamelNr~mber: ~,aty Ft~ble, 554-4944 Welt Number Permit No. J Approval No. DrrNfng Engineer: tl~lSTRUGTlC3NS GeneraL• This form is designed for submitting a complete and correct well completion report and log on ail types of (ands and [eases in Alaska. Submit a welt sehernatic diagram with each 10-+107 wail completion report and 1t)-404 well sundry report when the downhate yell design is changed. Item 1a: Classification of Service Wells: Gas injection, Water injection, Water Alternating-Gas injection,. Salt Water Dispnsai, Water Supply for trajection, Observation, or Other. Multiple completion is defined as a wail producing from more than one pool with: production from each pool completely segregated. Each segregated pool is a completion. item 4b TPt (Top of Producing IntervaiJ. Item $; The Kelly 8ustring and Ground Level elevation in feet above mean sea level tlse same as reference for depth measurements :given in other spaces on thisform and in any attachments. item 13: The API number reported fo AOGCC must be 94 digits.{ex: 50-029-20123-fl0-p0}. item 20: Report true vericatthickness of permafrost in Box 20. Provide MD and TVQ forthe top and base of permafrost in Box 28. i#em 23: Attached supplemental records for this welt should showthe details of any multiple stage cementing and the location of the cementing tool. item 24: if this well is completed for separate production from more than one interval {multiple completion), so state in item 9, and in item 23 show the .producing intervals for only the interval repaeted in item 25. {Sgbmit a separate form for each additional intenrai to be separately produced, showing the data pertinent to such intenrai). ttem 27: Me#hod of Operation: Flawing, Gas Lift, i2od Purnp, Hydraulic Pump, Submersible, Water injection, Gas injection, Shut-Ih, ar Qther (explair'+}, item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this bort. Submit detailed description anr3 analytical laboratory information requued by 20 AAG 25.079. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief aummary in this box: Submit detailed test and analytical laboratory information required by 20 AAC 25,071. Form 90-407 Revised 92/2009 SubmitOriginafC3niy i WELL NAME: B-02A r 23, Attachment - Casin ,Liner and Cementin Record Casing Setttn DeFth MD Setting De ih ND HOIe Size W#. Per l=#. Grade Top Bottom lop Bottom Size Cementing Record 30" Stave Pipe Surface 107' Surface 107' 36" 150 sx PermafrosE 20" 94# l 133# H-40 / K-55 Surface 2308` Surface 2308' 26" 5100 sx Permafrost 16" 65# H-40 / K-55 Surface 2192' Surface 2192' NIA Circulatin ,Not Cemented 13-318" 61 # / 68# H-40 / K-55 Surface 4545' Surface 4323' 17-112" 1200 sx Class 'G' 9-5/8" 47# L-80 Surface 1968` Surface 1968' 12-114" 3530 sx Class 'G' 10-3/4" 55.5# K-55 1966' 2380' 1968' 2380' 12-1/4" 9-5/$" 47# N-80 2380' 5663' 2380' 5196' 12-1/4" 7" 29# 13Cr / L-80 5465' 10385' 5042' S6i3' 8-112" 225 sx Class 'G' 4-1 /2" 12.6# 13Cr 10167 12283' 8458' 9075' 6" 66 sx Class'G',168 sx Class'G' ~iR~= '7.1,16" CAMERON WELLH_EAD= MCE110Y ACTUATOR= BAKER KB. ELEV = 68.68'. BF. ELEV = 40.57 KOP = Max Angle - Datum MD - _....m Datum TVD = _2750' 82 ~ 10879' 10983' __.. _. 8800' SS TOP OF FiSN ~ B-02A ~ FROM DRLG -DRAFT SUSPENDED OYON '16 ,1 ~ ~~, 13-3/8•• CSG, 68#, K55, ID = 12.41.5" 4545' 3-518" x 10-314" X-Over 196$. 10-314" CSG, 55.5#, K-55, .11325 bpf. ID = 9..76" 2380` 7" LNR, 26#, L-SQ, .0383bpf, ID = 6.276'" ~- 5465' ~~ 9-5t8'" X 7" BKR PKR /TIEBACK, ID= 7.50" 5465' 9-5/8"' X T' BKR LNR'. HGR, ID = 6.1 $" ~v' 479' ~ 625' 4-1/2" HES "XN" NIP, Ip = 3.725" 636' 4-1/2" 12.6# L-80 NSCT Workstring 725' T Susp Plug O C . . . . , 800' HES 'Fasdrill' Bridge Plug 1200` Top, Cut 4-1/2" Tubing 1415' Jet Cut, 4-1/2" Tubing _ 1720' Jet Cut, 4-1/2" Tubing NOTE :WELL WAS LEFT W/ 9.8 NaCI BRINE IN ANNULUS AND 20BBLS DIESEL F/P. 9-518" CSG, 47#, N-80, ID = 8.681" ~ 5663` ~J ~ 10048' Chemical Cut, 4-1/2" Tubing - - - 10124' HES 4-1/2" 'Fasdrill' Bridge Plug 10104' 4-112" HES X NIP, ID = 3.813" ._. 11}115' 7"X4-112" BKR S-3 PKR, ID - 3.875°' 813" ' 1013$' '4-112" HES X NIP ID = 3 . 10159' 4 112 HES XN NIP, 1D 3.725"~ 7" X 4112" TNYTIEBACK PKR W/ SEAL ASSY 10167` ...... = 3 " „ ` 4-1 /2" TBG, 12 6#, L80, .0152 bpf, ID = 3.958" 10169' 4-112 WLEG, !D 958 10171 7" X 4-112" TIW S-6 PK~EBACK, ID = 3.850" ~- j 1p!174 TNV DTH LINER HANGER, ID = 3.922° 10185` 7"" LNR, 29#, 13-CFt-8Q, .0371 bpf, ID=6.184" 103$5' PERFORATION SUMMARY REF LOG: AWS BRCS 07/29/96 A NGLE A T TOP PERF: 48 ~ 10400' Note' Refer t€s Production. DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2"' ' 4 10400 -10410 C 08/17/97 2" 4 11920 - 11940 O 10101199 3-318" 4 11960 - 11970 O 03125/97 3-318" 4 11370 - 11990 O 10113196 2-118" ' 4 12012 -12032 O 03129/96 1.56" 4 12040 - 12050 S 08/01/96 2" 4 12090 - 12110 O 10/09/99 3-3/8" ' 4 12125 - 12145 O 03/25197 3-318" 4 12145 - 12165 O 10113/96 2"' 4 12140 - 121' 60 O 09/28/96 10386' 4-112" AVA DW RETR. PATCH, iD =' 2.449'" TOTAL LENGTH = 35' 7" (08117!97 ) PBTD H 12180' 4112" LNR, 12.6#, 13-C,.0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 11109(17 ORIGINAL. COMPLETION 08/11106 MWS PROPOSED RWO 08119/96 RIGSIDETRACK 49127106- pag SUSPEM1tDEI:}CflRRECTIONS 07104101 CWKAK CORRECTIONS 06/07/02 RL/tlh GLV UPDATE 03121103 JDW/KK PERF CORRECTIONS 03128103 JCfWTLH GLV UPDATE PRUDHOE BAY UNIT WELL: B-02A PERMf1' No:''1961110 API No: 50-029-20066-01 SEC 31, T11 N, R14E, 961' SNL & 1598` WEL BP Exploration (Alaska) • L~ ~~~~~ ~~ ~ ~ ? a SEAN PARNELL, GOVERNOR 7 ?.r tr+~ k. DiK~*7i>•LL'1. OII/ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7`IO1Q CODil•'II5SIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Al Schmoyer Senior Pad Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ta6'~~I Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU B-02A Sundry Number: 310-027 ;,, z Dear Mr. Schmoyer: 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this 1 day of March, 2010 Encl. Commissioner ,O STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISSI~~ / APPLICATION FOR SUNDRY APPROVALS ~~ 20 AAC 25.280 it ` w ~o JAN ~ ~ 2Q1Q Alssk~l 00 ~ Gaya Conn. COlrt~nlssiA~a '- ----- 1. Type of Request: Abandon ^ Plug for Re^I Perforate New Pool^ Repair Well^ Chan rogram^ Suspend^~ Plug Perforatio^ Perforate^ Pull Tubing^ Time Extension^ V^I Stimulate^ Alter Casing ^ Operation Shutdown ^ Re-enter Susp ^ . Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ^ 196-1110 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorege, AK 99519-6612 50-029-20066-01-00- 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: ^ ^ ~ PBU B-02A Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028310 - Prudhoe Bay Field / Prudhoe Bay Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12283 ~ 9075.28 - 725 725 800' 10124' TOC 725' 1224' Casing Length Size MD TVD Burst Collapse Structural 107 30" 157.5# B GRADE 28 135 28 135 880 Conductor 2281 20" 94#/133# H-40/K-55 27 2308 27 2308 1530/3060 520/1500 Circul String 2166 16# 65# H-40 26 2192 26 2192 1640 630 Surface 4520 13-318"61#/68# H-40/K-55 25 4545 25 4323 3090/3450 1540/1950 Production 1944 9-5/8" 40# N-80 24 1968 24 1968 5750 3090 Production 412 10-3/4" 55.5# K-55 1968 2380 1968 2380 6450 4020 Production 3283 9-5/8" 47# N-80 2380 5663 2380 5196 6870 4760 Liner 3920 7" 29# 13CR80/L-80 6465 10385 5774 8613 8160/8160 7020/7020 Liner 2116 4-1/2" 12.6# 13CR80 10167 12283 8458 9075 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 22 10171 - - 4-1/2" AVA DW RETR PATCH 10386 10422 Packers and SSSV Tvoe: 9-5/8"BKR PKR/TIEBACK Packers and SSSV MD and TVD (ft): 5465 5042 7" BKR S-3 PKR 10115 8420 7" TIW PKR/TIEBACK 10167 8458 7" TIW S-6 PKR/TIEBACK 10174 8463 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q' Service ^ 14. Estimated Date for 15. Wel Status after proposed work: Commencing Operations: 2/10/2010 ~ ~ Gas ^ WDSPL ^ Plugged ^ 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 AI Schmo er Printed Name AI Schmo i r Title Senior Pad Engineer Signature Phone Date } 564-5865 1/27/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY /l (.i ~ ~~ 7 resentative may witness Sundry Number: roval: Notif Commission so that a re Conditions of a y p pp ,, c e ^ est ^ Location Clearan ^ BOP Test ^ Mechanical Integrity T Plug Integrity ' l n ) ~ / Other: yVG!/$/.~ /r1S G~e~O~. PLptiu^~al~ Ir.'1~~+'~ ~Z Iwo,LTa-s, ~ Subsequent Form Required: ~Q ' Y APPROVED BY ~ /~ Approved by: COMMISSIONER THE COMMISSION - Date: M MAR 0 2 20~ :~~ z./.!a Form 10-403 Revised 12/2009 D" "~ Submit in Duplicate ~ ~=/o B-02A 196-111 DFRG ATTArNMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base B-02A 8/6/96 PER 12,040. 12,050. 9,012.25 9,013.88 B-02A 8/7/96 PER 10,400. 10,410. 8,623.73 8,630.55 B-02A 8/13/96 SQZ 10,400. 10,410. 8,623.73 8,630.55 B-02A 8/13196 SQZ 12,040. 12,050. 9,012.25 9,013.88 B-02A 9/14/96 SQZ 10,400. 12,050. 8,623.73 9,013.88 B-02A 9/28/96 PER 12,012. 12,032. 9,007.62 9,010.94 B-02A 9/28/96 PER 12,140. 12,160. 9,029.49 9,033.82 B-02A 10/13/96 APF 12,145. 12,165. 9,030.52 9,035.02 B-02A 10/13/96 RPF 12,012. 12,032. 9,007.62 9,010.94 B-02A 10/13/96 APF 11,970. 11,990. 9,000.5 9,003.91 B-02A 3/25/97 APF 11,960. 11,970. 8,998.79 9,000.5 B-02A 3/25/97 RPF 12,125. 12,145. 9,026.53 9,030.52 B-02A 3/29/97 BPS 10,400. 10,410. 8,623.73 8,630.55 B-02A 10/1/99 APF 11,920. 11,940. 8,991.95 8,995.37 B-02A 10/1/99 APF 12,090. 12,110. 9,020.3 9,023.74 B-02A 8/22/06 BPS 10,124. 10,400. 8,426.28 8,623.73 B-02A 9/23/06 BPS 800. 802. 800. 802. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE `I Subject: Application for Suspended Status Well: B-02A B-02a Summary: RWO operations to restore wellbore integrity in B-02a were started on September 12, 2006 and suspended on September 23, 2006. The Rig struggled to mill a cement donut left in the inner annulus during a March 2003 OA circulation squeeze that took returns up the IA. The Rig was making slow progress washing over the 41/2" tubing and cement and started getting metal returns indicating damage to the 9-5/8" production casing. The Rig shut down operations after 11 days and RDMO to evaluate options. The complexity and difficulty of forward operations resulted in the decision to not resume the RWO at that time. A Sundry was filed with the State for "Operation Shut Down". The RIG left B-02a with a Baker Quickdrill composite plug in the 4 1/2" tbg at 10,124', the tbg cut and pulled from 1200', a HES Fasdrill composite BP in the 9 5/8" casing at 800' with 75' of cement on top of the plug and 636' 41/2" workstring. Operations History: > 02/28/02: CMIT IAxOAxO0AxOO0A Passed > 07/10/02: OA x OOA Cemented from Surface to 2100' w/ 11 ppg Arctic Crete. > 01/25/03: MITOA Failed. LLR=0.1 gpm at 1050 > 03/17/03: Circ Sqz arctic set cmt down OA taking returns up IA > 07/25/04: MITOA Passed to 2000 psi > 07/30/04: IA will not take gas lift > 09/22/04: SCMT log found cement in the IA from 830' - 1780' MD. > 09/09/05: CMIT OOAxOOOA Passed to 1000 psi > 08/10/06.: PPPOT-IC Passed to 3800 psi; LDS functioned > 09/02/06: CMIT-TxIA Passed to 1000 psi > 09/12/06: Doyon 16 MIRU for RWO > 09/23/06: Doyon 16 suspended RWO operations. >~- ~ ~r9ri~c:RntJx~a,~ .acn~rrex~- eal~x ItII. acs - ~f. ~~v - ~o.e~ ao.tir- KOA - x397 9v9ax Ar~gk - fAtanAA']= f~alvin TLj~ - •32 ~ 1(98?6 it~ss Hi4f1[k' ~:~ 9/23/06 Doyon 16 Suspended RWO Operations ~~~~ FRt7M DRLG -DRAFT G25' i11~' FrBB'XM !!~, D r x1.74!!' 41 ~ 12Af 4B6 MI$CT 725' Tom- , ~A "BS,eKdpaPYg 1200' Tap• ~ s.trr 1419' .ter {~ 41@' 17201' •rid ~ 4.11@' 74ibirg r~--~ 1, H 1224' i 3.3.+8•' CS{~ 6,~R. K55, ~ - 12 Ai 4'~~ $~ I- ~- 9.6,.3° x 99>&~4.7C-t~rer 1$G~° 5~~+4" CS+L-, S6.5aF. K•SS..4925 ~pf. ID - ~_7B' 23~Q Nt}TE : WELL YIr7P-S LEFT W/ 9-$ NaCI BRNE IN AM+R)LUS f~lVd 20BBLS ~ESEL F!P! Lhg2 28N. L->!>}, .fly, ID - 9.27g• H 54915' ~-~• X r • BIO: P4~1R; l'FHACK, ~ = 7.~r• 5+165• 5~~8' % 7" B{R LM4i HGR. ~1- 6.18• 5479' r x a-•~r~' acv I .cK t~~t vac seal ~ssr [ 10167' a-a,+L" alit; i z.6+a. L2U..{11 J? Cpl, Cl = a.9+a8" ~--~ 101~i~ 10448' 9~uerstimi9:>twN.+ti.It'7iit 10124' FES~-1 ~2"Fam~ etitlge P~ 10~- j4-1!'?"' HES % HF; ID- 3.91:' 10115' H7'x47r?"fiKRF;R4R,I~••.l 141#8' N 4~!-s"HFwxr~~.n~_~~1=• 10171'.. ~airr wt Fc~, n = :~ £' % ~-1.'1' I hti' Sys, F'ICFa' I ki3,4€~c. ~7 = 3.36[~~ ~ t41 ~ TrNrr~~+i a~t9aaar~, in=:~ga~• H rotes 7" LNf2. ?9>€, i~-Glt~ev. -4371 hFf. ~ - 6. f 3~' 1#738! ~r9.~rnn€~~ su.~+u-lxr R~ LOG: A4V5 BH-~ ]7.+~1+'d6 A~I.E A l lOF' a'tJiF' 4tf ID? i U+IQIX Nab: FEefrr Lo ftotA,ctamn I7a31ot hlaaarlcaa ri d~-,3 S¢E SPI' DlIEStllr\L apru'Sge 4r\7L r 4 11 f+:t4 -1 i 94a1 U 1 auul ~5W 3-P,~B' +# 111264 - i 191D ~ O'u'2a++&~1 3-3.+E' A 119x74 - 1189Q G 1 CV13+1)9 'l-lras 4 IFJ13 ~ i1L1S1 tl +JyP~i+yt3 9 -+Ci- 4 i h14t1- i JI7~S 5 SIR+M!TitS 2" 4 92t~90- 12910 t1 1Q+Q1!'a2 ~~'a 9 t'~125- 1445 Ll +7~:5~~77 ~" $ 4z14t1-i?ifl] Q =1171+7R+7+~i I 1 D386' I a ~!z r.wn uyv ~c~in. rrtu.r~a.!^taa~ T9.7T4 L LEtifilM = 39 7' t 4O.'I'rt'37 5 14-1!Z' LNR. 12.5iE, 1~-C.:0152 l~sf. D- 3.648" [7157[ RLV RY CCINI€MT' CYl7L RL~I [iY t~t]111uE#!i~ 11 109+'x'7 4Ri~U.L iXiM~LL'TIDN OB.'1 i 106 BINS PAv3P935LD RV~~G 413J'1Ear'~8 9tK:SC~1F.A+t;FC ^J~i:~7S~6 pa4 ~tA~yPFt~7Ff:C~RRECTL'71+~i 07~4C+1 GWICp.K [:URRE4TgUh05 06~W7,+L2 I~tl~ GLV t1~P.TE 913d7'1lLti3 J~NpFsK 1'ERF {:ORRIECT)<ll+JS 03~.si+L+3 JCtS+Tlti GLV' 9.R'~kTE 9~RLI01lC[ E1hti' UNR VJ~L: Q 0?Ji F~RIAT l+b• ~ 9x51.1 p !~ PI rlo: 54-019-~Q4~G-01 711!1 FI9+4~ 951' 3A1.~1525''liV~ BP6plor~iinh (Alacka~ • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 r~ L ~p '°:~ Dec 11, 2009 ,. ~ ~ ~5 ~s ~ ~.:^~ f ° ~ i i `~ 1 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, ~! . _ ,. ~ tJridi's,6a4i'f~~ i~~~ ~~i ~- o~-.a Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date: 12/11/09 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-056 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 8-09 .1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 8-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLS 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 200Q570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA sk:. lJ: 1. Operations Performed: .,. Q{ Q&$ P . AbandonD Repair WellO Plu! PerforationsD Stimulate 0 9twt?hé;e·~· CQn"lflU " Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionE1l1e Change Approved ProgramD Operation ShutdownŒ Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 1 gø..111 0 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20066-01-00 7. KB Elevation (ft): 9. Well Name and Number: 68.50 B-02A 8. Property Designation: 10. Field/Pool(s): ADL-028310 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12283 feet Plugs (measured) T.O.C. Susp. Plug @ 725' (09/22/2006) true vertical 9075.0 feet HES Fasdrill BP set @ 800' (09/22/2006) Effective Depth measured 725 feet Baker Quickdrill @ 10124' (08/22/2006) true vertical 725.0 feet Junk (measured) Top of Fish @ 1224' Casing Length Size MD TVD Burst Collapse STRUCTURAL 107 30" 157.5# B Grade 28 - 135 28.0 - 135.0 880 CONDUCTOR 2281 20" 94#/133# H-40/K-55 27 - 2308 27.0 - 2308.0 1530/3060 520/1500 ::IRCUL STRING 2166 16" 65# H-40 26 - 2192 26.0 - 2192.0 1640 630 SURFACE 4520 13-3/8" 61#/68# H-40/K-55 25 - 4545 25.0 - 4323.0 3090/3450 1540/1950 PRODUCTION 1944 9-5/8" 40# N-80 24 - 1968 24.0 - 1968.0 5750 3090 PRODUCTION 412 10-3/4" 55.5# K-55 1968 - 2380 1968.0 - 2380.0 6450 4020 PRODUCTION 3283 9-5/8" 47# N-80 2380 - 5663 2380.0 - 5196.0 6870 4760 LINER 3920 7" 29# 13Cr80/L-80 6465 - 10385 5774.0 - 8613.0 8160/8160 7020/7020 LINER 2116 4-1/2" 12.6# 13Cr80 10167 - 12283 8458.0 - 9075.0 8430 7500 Perforation depth: ~-;¡('l\ .... 2: ~?: 2fJ!lR ."".""" "' ·.'\!tr:F)J , .... I.;L[) Measured depth: 10400-10410,11920-11940,11960-11970, 12012-12032, 12090-12110, 12125-12165 True vertical depth: 8623-8630,8992-8995,8999-9000,9008-9011, 9020-9024, 9027-9035 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 22 - 10171 4-1/2" AVA DW RETR Patch @ 10386 - 10422 AVA RETR Patch Packers & SSSV (type & measured depth): 9-5/8" BKR Packer/Tieback @ 5465 7" BKR S·3 Packer @ 10115 7" TIW PKR/Tieback @ 10167 with Seal Assy 7" TIW S-6 PKR/Tieback @ 10174 4-1/2" HES HXO SSSV Nipple @ 2204 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv AveraQe Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI 0 0 --- 0 Subsequent to operation: SI 0 0 --- 0 14. Attachments: 15. Well Class after proposed work: ExploratoryO DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasO WAG 0 GINJO WINJO WDSPLO Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr 306-276 1 306-328 Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~L. ~ .AI? j¿ JI ./ Phone 564-5174 Date 10/19/06 - . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~ RËCË/\tF::D OCT 1 9 2006 ~¡Ofl Form 10-404 Revised 4/2004 0 R \ G \ N A L RBDMS BFt OCT 2 0 znOfi TREE = 7-1/16" CAMERON Il\e.LHEAD= MCEVOY ACTUA TOR= BAKER KB. ELEV = 68.68' BF. ELEV = 40.57' KOP :: 2750' Max Angle = 82 @ 10879' Datum MD :: 10983' ---~_. Datum TVD = 8800' 5S TOP OF FISH B-02A FROM DRLG - DRAFT 1224' 113-3/8" C5G, 68#, K55, ID= 12.415" H 4545' 19-5/8" x 10-314" X-OVer H 1968' I 110-3/4" CSG, 55.5#, K-55, .0925 bpf, ID = 9.76" H 2380' 17" LNR, 26#, L-80, .0383bpf, ID = 6.276" I 19-5/S" X 7" BKR PKR / TIEBACK, 10:: 7.SO" H 9-518" X 7" BKR lNR HGR, 10:: 6.18" , 9-518" CSG, 47#, N-ao, ID:: 8.681" I 7" X 4-112" llWTlEBACK PKRW/ SEAL ASSY 4-112" TBG, 12.6#, LSO, .0152 bpf, ID :: 3.958" 7" LNR, 29#, 13.CR-80, .0371bpf, 10=6.184- , 7- X 4-112" llW 5-6 PKRlTEBA CK. 10 = 3.8SO" llW DTH LINER HA NGER, ID = 3.922" 10385' ÆRFORA TION SlM4ARY REF LOG: AWS BHeS 07129196 ANGLE AT TOP ÆRF: 48@ 10400' Note: Refer to R'oduction DB for hístorical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10400 - 10410 C 08117/97 2" 4 11920-11940 0 10/01/99 3-3IS" 4 11960 - 11970 0 03125/97 3-3/a" 4 11970-11990 0 10/13/96 2-1/8" 4 12012 - 12032 0 09/29/96 1.56" 4 12040 -12OSO 5 08101/96 2" 4 12090 - 12110 0 10/01f99 3-3/8" 4 12125 - 12145 0 03125/97 3-3/S" 4 12145 - 12165 0 1 0/13196 2" 4 12140 - 12160 0 09/28/96 DATE 11/09m 08/19196 07/04101 06107/02 03121103 03/28103 REV BY COM\£NT5 ORIGINA L COMPlETlON RIG 5DETRA CK CHIKA K CORRECTIONS RUtlh GLV UPDATE JOWIKK ÆRF CORRECTIONS JCM'l'lH GL V lJPDA TE DATE 08/11/06 09/27/06 SUSPENDED 09/23/06 - DOYON 16 ~ 4-1/2" HES "XN" NIP, ID = 3.725" ~ 4-1/2" 12.6# L-BO NSCT Workslring I 725' T.O.C. , Susp. Plug I 800' HES 'Fasdrill' Bridge Plug I 1200' Top,Cut4-1/2"Tubing I 1415' Jet Cut, 4-1/2" Tubing I 1720' Jet Cut, 4-1/2" Tubing NOTE: WEll WAS lEFT W/9.8 NaCI BRINE IN ANNULUS AND 20BBlS DIESEL F/P. 110048' I Chemical Cut, 4-112" Tubing 110124' I HES 4-1/2" 'Fasdrill' Bridge Plug 10104' 10115' 10138' 10159' 10171' H4-1/2" HES X NIP, ID:: 3.813" I 7" X 4-1/2" BKR 8-3 PKR, ID :: 3.875- H4-112" HES X NIP, ID = 3.S13" I H 4-1/2" HES XN NIP, ID = 3.725" 1 4-112" VllLEG,ID = 3.958" 4-112" A VA rJN RETR. PATCH, 10 = 2.441" TOTAL LENGTH = 35' 7" (08117197) ïTD H 12180' I 14-1/2" LNR, 12.6#, 13-C,.0152 bpf, 10= 3.958" H 12283' I REV BY COWENTS MoNS PROPOSED ~ pag SUSPENDED CORRECTIONS PRUDHOE BAY UNfr WB.L: B-02A PERMIT No: '1961110 API No: 50-029-20066-01 SEC 31, T11 N, R14E. 961' 5NL & 1598' II\e. BP Exploration (Alaska) . . B-02A DESCRIPTION OF WORK COMPLETED EVENT SUMMARY AWGRS 08/10/2006 T/IAlOAlOOA = SIIO/O/O (Pre-Rig Workover Inspection) PPPOT-IC = PASSED PPPOT-T = PASSED Bled inner casing void to 0 psi. Tighten Rockwell style lockdown pins. Energized "Y" seals with (6) sticks of Cameron packing. Rigged up test equipment, pumped until clean fluid returns were achieved. Tested void to 3,800 psi. for 30 mins. - Passed. Bled tubing hanger void to 0 psi. FunctionedlTorqued lockdown screws to 550 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 5,000 psi. for 30 mins. - Passed. AWGRS 08/12/2006 **** WELL SHUT IN ON ARRIVAL *** (PRE CIBP/ RWO) RAN 3.80 LIB TO 773' SLM SHOW 3.25 OPENING. DRIFT WI 3.0 SWAGE TO 10,200' SLM. DRIFT WI 3.625 SWAGE AND 3.625 G. RING. TO 10,200' SLM. ***LEFT WELL S/I*** PAD OP NOTIFIED AWGRS 08/16/2006 T/I/O/OO/OOO= 300/300/80/0/na. WHPs TBGP & FL (pre - Fasdrill). TBG is cut @ 799', FL appears to be 1500' (23 bbls). AWGRS 08/21/2006 TII/O/OO/OOO = 400/320/0/0/NA - Load IA and TBG w/9.8# Brine. (RWO Prep) Bleed gas cap off IA. AWGRS 08/22/2006 WELL SHUT-IN ON ARRIVAL. T/I/O/OO = 275/210/100/0 SHOT 2 STRAND 80 GRAIN, 12' STRING SHOT OVER INTERVAL 10,037-10,049 FT. SHOT TUBING PUNCHER FROM 10010' - 10012'. SET 4-1/2" BAKER QUICKDRILL AT 10124' MID ELEMENT. *** JOB COMPLETE*** AWGRS 08/22/2006 T/IIOIOOIOOO = 400/1501010/NA - Load IA and TBG w/9.8# Brine (Pre RWO)- Pumped 5 bbl meth spear followed by 60 bbls 9.8# brine and 2 bbl meth cap. Pumped 5 bbls meth followed by 200 bbls 9.8# brine and 2 bbl meth cap. FWP's = vac/80/100/0/NA AWGRS 08/29/2006 TII/O/OO/OOO = 330/3401?/0+1? Temp = SII' No AL to well. WHPs and FLs (pre- rig). TBG FL @ 636' (8 bbLs). IA FL @ 3692' (200 bbLs). AWGRS 08/30/2006 TIIIOIOO/OOO=330/350/70/0/0. Temp=SI. Bleed WHP's to 0 psi. (Pre-RWO). TBG & IA FL's unreadable. Bled TP & lAP to 0 psi in 6 hours. Bled OAP from 70 psi to 0 psi in 1 hour. No fluid was returned during bleed's. Final WHP's=OIOIO/OIO. AWGRS 08/31/2006 T/IIOIOOIOOO = 0/0/01010 Temp = SI CMIT TxlA Loaded IA w/105 bbls 65* crude. Job postponed. FWPs = 0101010 AWGRS 08/31/2006 T/I/OIOOIOOO=1 0/10/1 01/0/0. Temp.=S/1. WHP'S. (Post bleed). TP increased 10 psi overnight. lAP increased 10 psi overnight. OAP increased 10 psi overnight. OOAP and OOOAP no change overnight. (AL line and FL are disconnected from well and blinded at lateral valve). AWGRS 09/02/2006 T/I/O/OO=010/6010 CMIT Tx IA to 1000 psi. (PASS) Load TBG & IA w. 9.8# Brine. (Pre RWO) Pumped 7 bbls of neat meth and 200 bbls of 9.8# brine down TBG, taking returns from lA, down jumper line to well # 1. ***CMIT TxlA. Pressured up TBG & IA w. 18.5 bbls 9.8# Brine TBG and IA lost 20/20 psi in the first 15 min, and 01 o psi in the second 15 Min. TBG and IA lost a20/20 psi in 30 Min. Final WHP's=400/400/20/0 Page 1 . . '- B-02A DESCRIPTION OF WORK COMPLETED AWGRS 09/03/2006 T/I/O/OO/OOO=360/360/20/0/0 Temp=SI Bleed WHPs to 0 psi (pre-rig). TBG & IA FLs near surface. Bled lAP from 360 psi to 260 psi in 3 hours by bleeding off the gas then shutting in bleed every 15 minutes to let gas swap out with fluid. Bled TBGP from 360 psi to 260 psi in 3 hours the same way, gas then fluid, shut in, let swap out then continue. Bled back a total of 6 bbls to slop trailer. Monitor for 1 hour while grader preps location for rig. TBGP increased to 350 (90 psi gas cap) & lAP remained unchanged. Swapped TBG & IA bleed to gas buster tank #029. Bled TBGP (350 psi) & lAP (260 psi) simultaneous to 60 psi in 4.5 hours (3 bbls returned). Bled OAP from 20 psi to 0 psi in 15 minutes. Continue tomorrow. Final WHPs=60/601010/0 AWGRS 09/03/2006 T/I/O=600/520/0 Load tbg w 9.8 brine (Pre RWO) Pump remaning xx bbls 9.8 Brine down tbg taking returns up IA to B-01 FL, freeze protect B-01 FL w. 7 bbls neat 85 bbls crude FWHP= 300/30010 DIMS 09104/2006 MIRU on B-02a. Pull BPV. AWGRS 09/04/2006 SET BPV /PRE RIG AWGRS 09/04/2006 T/I/OIOOIOOO = 110/100171010. Temp = SI. Bleed WHPs to 0 (pre RWO). Tubing pressure increased 50 psi overnight. lAP increased 40 psi overnight. Tubing & IA FLs near surface. Bled lAP to 0+ psi in 3 hrs, 5 min (all gas). Bled Tubing pressure to 0+ psi in 2 hrs, 35 min (all gas). SI, monitored for 30 min each. No change in pressures. Bled OAP to 0 psi in 10 min (all gas). SI, monitored for 30 min. OAP increased to 0+. Final WHPs = 0+/0+/0+1010. AWGRS 09/04/2006 PULL BPV, RIG MOVED ON WELL DIMS 09/05/2006 DIMS 09/06/2006 DIMS 09/07/2006 PT Down Hole Plug to 1000 psi. Circ Out Diesel and Crude wI 9.8 Brine. Set TWC and PT Above and Below. N/D Tree & N/U BOPE. Test BOPE. C/O #6 Choke Manifold Valve, C/O Hydril Element, Install 2-7/8" VBR's, Attempt to Test BOPE, Wait on 2-7/8" Solid Body Rams C/O Rams and Test, Repair Hydril and Test, N/U Shooting Flange, R/U DSM and Pull TWC, Circ Well w/9.8 ppg Brine. DIMS AWGRS 09/07/2006 PULL TWC, RIG TESTED BOP'S DIMS DIMS DIMS DIMS DIMS DIMS 09/08/2006 R/U E-line, Chem Cut tbg, Punch Tubing, Circ out gas. RIH wI Punch 09/09/2006 Punch and Cut tubing with E-Line, Lubricate and Bleed Gas from Welfbore. 09/10/2006 Monitor Well, Lubricate and Bleed out gas and Crude. 09/11/2006 Lubricate and Bleed, Gas and Crude from Welf 09/12/2006 Lubricate and Bleed, Gas and Crude from Well 09/13/2006 Cont Bleed Press & Circ Out Crude, Spot Kill Pill, RIH w/ BHA. Strip In Hole V 1760', Cont Stagging In Hole 09/14/2006 Stage RIH, Circulate Well Dead, POOH Page 2 . . B-02A DESCRIPTION OF WORK COMPLETED DIMS 09/15/2006 POOH wi 2-7/8" DP, CIO Rams, Test BOPE, POOH wi 799' TBG, Fish 1600' Control Line AWGRS 09/15/2006 PULLED TWC. RIG TESTED BOP'S DIMS 09/16/2006 DIMS 09/17/2006 DIMS 09/18/2006 DIMS 09/19/2006 DIMS 09/20/2006 DIMS 09/21/2006 DIMS 09/22/2006 Fish Control Line, RU and RIH wi WashPipe and Burn Shoe, Mill Annular CMTf/817' to 900' POOH wi WashPipe, CIO Mill, RIH, Mill f/900'-933', POOH wi TBG Fish, LD Fish, CIO Mill, RIH RIH, Mill f/933'-941', POOH, CIO Mill, RIH, Mill f/941 '-1 034' Cont to Mill f/1 ,034' to 1,062'. POOH, CIO Mill Shoe, RIH, Continue Washing Over Tubing f/1,062' t/1,101', POOH LID Fish and Wash Pipe, RIU and Test 9 5/8" Csg to 1,000 psi, RIH w/8 1/8" Shoe and Wash Pipe to 1,101' Continue Milling Cmt and Junk to 1,186', POOH. LID 80' of 4.5" Tubing Fish, Cut and Slip DRLG Line, RIH to 1,172', Continue Milling to 1,224', Pump Sweep, POOH, Test Choke Manifold. Test BOPE, RIH to 1,200'. Test Casing, Decision Made to T/A Well, Displaced Well To 9.8 ppg Brine. LID Drill Collars and Wash Pipe. RIH Set Fas-Drill @ 800', Set Balanced CMT Plug, POOH LID Drill Pipe, RIU to Run 4.5" 12.6#, L-80, NSCT Kill String. DIMS 09/23/2006 Run 4.5", L80, 12.6# NSCT Kill String, Landed Kill String, N/DBOPE, N/U Production Tree, Tested Tree, Pumped Freeze Protection, RID M/O. AWGRS 09/23/2006 T/IA/OA=O/O/O assist Cameron with lining up tools for stuck LOS due to metal shavings in spool from sidetrack. ***Torque eliminator Page 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/4/2006 16:00 - 18:30 2.50 MOB P PRE Move Rig From B-36 to B-02a. 18:30 - 19:30 1.00 RIGU P PRE Position Rig Over Well. Spot Pump Room, Motor Complex and Slop Tank. 19:30 - 22:00 2.50 RIGU P PRE Rig Up #2 Pump and #4 Generator. Rig Up Hoses and Manifold to Circ Out Freeze Protect. Accept Rig at 22:00 hrs 9/4/2006. 22:00 - 23:30 1.50 WHSUR P DECOMP Load Lubricator into Pipe Shed. P/U Lubricator to Floor and Pull BPV. UD Lubricator. 23:30 - 00:00 0.50 KILL P DECOMP RlU to Tree Cap to Clrc Out Freeze Protect. 9/5/2006 00:00 - 01 :00 1.00 KILL P DECOMP Load 150 bbls of 9.8 ppg Brine into Pit #3. Pressure Test Lines and Hoses to 3500 psi. 01 :00 - 02:30 1.50 DHB P DECOMP Pump down Tbg with 57 bbls and Stage Pressure Up to 1000 psi and Hold for 30 mins. 02:30 - 03:30 1.00 KILL P DECOMP Pump 20 bbl High Visc Sweep and Chase with 60 bbls of 9.8 ppg Brine at 4 bpm and 220 psi. A good volume of crude seen in retums. 03:30 - 05:00 1.50 KILL P DECOMP Wait on additional 9.8 Brine to arrive on location. 05:00 - 06:30 1.50 KILL P DECOMP Fill Pit #3 and Circulate another 20 bbl High Visc Sweep and Chase with 200 bbls of 9.8 ppg Brine. 06:30 - 08:30 2.00 KILL P DECOMP Monitor Well and Wait on DSM to arrive on location to set TWC. 08:30 - 10:30 2.00 DECOMP Set TWC with DSM Lubricator. Test annulus to 1000 psi for 10 mins. Test Tree to 3500 psi for 10 mins. 10:30 - 11 :30 1.00 BOPSU DECOMP RID Pressure Test Equipment. RID and B/D Manifold. RlU Secondary Annulus Bleed Hose to Slop Tank. 11 :30 - 13:30 2.00 BOPSU DECOMP NID Tree and Adapter Flange. Prep Wellhead and Check TC4S Hanger Threads. 13:30 - 17:00 3.50 BOPSU DECOMP N/U BOP Stack and Install Flow Riser. 17:00 - 18:00 1.00 BOPSU DECOMP PJSM. RlU to Test BOP Euipment. 18:00 - 00:00 6.00 BOPSU DECaMP Pressure Test BOPE. 250 psi Low and 3500 psi High. Test Witnessed By BP WSL and Doyon ToolPusher. Witness of Test Waived by John Crisp of AOGCC. 9/6/2006 00:00 - 04:30 DECaMP Continue to Test BOPE, 250 psi Low 1 3500 psi High. Failures on Choke Valve #6 and Hydril Annular Element while Testing 4" Test Joint. 04:30 - 10:30 6.00 BOPSU RREP DECOMP Replace #6 Choke Valve. NID Flow Riser, Pull and Replace Hydril Element. 10:30 - 13:00 2.50 BOPSU DECOMP N/U Flow Riser. Tighten Up Bolts on Valve Number #6. Clean up Tools and Floor. 13:00 - 14:00 1.00 BOPSU DECOMP Pressure Test Choke Body to 250 psi Low and 3500 psi High. Pressure Test Valve #6 to 250 psi Low and 3500 psi High. Each Test for 51 min each, good test. 14:00 - 15:30 1.50 BOPSU DECOMP RlU and Install 2-7/8" VBR's 15:30 - 16:30 1.00 BOPSU DECOMP Test 4-1/2" Test Joint in VBR's and Hydril Element to 250 psi Low and 3500 psi High. Good Test. Koomey Test - Good Test. 16:30 - 17:30 DECOMP Attempt to Test 2-7/8" Test Joint in VBR's - Failed. Pulled Test Joint and Found Two Places that it looked like Test Joint was Pinched by VBR's. 17:30 - 20:30 3.00 BOPSU DECOMP Wait on new Test Joint to Arrive to Attempt Test Again. 20:30 - 21 :00 0.50 BOPSU DECOMP Pressure Test 2-7/8" VBR's. Fluid pumping by rams. Pull test joint, no marks on joint. 21 :00 - 22:00 1.00 BOPSU RREP DECOMP RlU and open lower ram bodies. Inspect 2-7/8" VBR's. Ram Printed: 9/2512006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: rubber split completely through. Locate and wait on 2-7/8" rams. 9/7/2006 RlU and open ram bodies, install 2-7/8" solid body rams in lower rams. 01 :00 - 02:00 RREP DECOMP Test 2-7/8" rams to 250 psi low pressure and 3,500 psi high pressure. Good test. 02:00 - 03:00 RREP DECOMP Attempt to pressure test Hydril. Tested to 250 psi low pressure but would not test to 3,500 psi high pressure. Worked Hydril element several times and attempted to re-test. Fluid was noticed coming from the back side of the element. 03:00 - 03:30 RREP DECOMP Rig down test assembly. 03:30 - 05:00 RREP DECOMP N/D Riser assembly. 05:00 - 06:00 HMAN DECOMP Troubleshoot Hydril Element. 06:00 - 07:00 HMAN DECOMP Pressure Test Hydril and 2-7/8" Test Joint. Pressure Test 250 psi Low / 3500 psi High for 5 mins - Good Test. 07:00 - 09:30 HMAN DECOMP Found that one of the Seals on the Hydril Element installed incorrectly when replaced earlier. Rig Down Test Equipment and Pull and C/O Upper "U" Seal. 09:30 - 11 :00 1.50 DECOMP Re-Test Hydril Element against 2-7/8" Test Joint. Pressure Test 250 psi Low /3500 psi High for 5 mins- Good Test 11 :00 - 11 :30 DECOMP Bleed Down and Rig Down BOP Test Equipment. 11 :30 - 12:30 DECOMP Flange Up 6-3/8" ID Shooting Flange with 7" Otis Connection to Top of Hydril. P/U 7" Lubricator Ext. 12:30 - 13:30 1.00 WHSUR N WAIT DECOMP Wait on DSM to Arrive on Location to Pull TWC with Lubricator. 13:30 - 15:00 1.50 WHSUR P DECOMP PJSM with Rig Crew and DSM on Pulling TWC & Bleed Down. P/U DSM Lubricator. Measure Out Distances to Get TWC above Blind Rams. Distance Req -120 inches. Max Stroke on DSM Lubricator = 96". Lubricator unable to work even with extensions, will be unable to get plug above blind rams. 15:00 - 18:30 3.50 WHSUR N WAIT DECOMP Consult Town and Veco Valve Shop on Options. Old Lubricator available w/ 200 inch Strock Length. Investigate Condition on Lubricator, Seals, and Polish Rod. Pressure Test Lubricator to 2000 psi in Valve Shop. 18:30 - 19:30 1.00 WHSUR P DECOMP RlU 7" Valve to top of shooting flange. 19:30 - 20:30 1.00 WHSUR P DECOMP PJSM with all personnel involved. RlU DSM 200" lubricator and M/U to 7" Valve. Pressure test to 2,000 psi. 20:30 - 21 :30 1.00 WHSUR P DECOMP Pull TWC. 90 psi pressure on tubing side 30 psi on IA. Close blinds and bleed pressure off lubricator. 21 :30 - 22:00 0.50 WHSUR P DECOMP RID DSM 200" Lubricator. Clear rig floor. 22:00 - 23:30 1.50 KILL P DECOMP RlU and pump down IA and take returns out tubing through choke manifold. 60 bbls of hole volume. Pumped 162 bbls of heated 9.8 brine till well cleaned up. Approximately 10 bbls of crude returns upon initial circulation. 3 bpm at 240 psi. 23:30 - 00:00 0.50 KILL P DECOMP Shut in and monitor well on tubing and annulus. 9/8/2006 00:00 - 01 :30 1.50 KILL P DECOMP Monitor pressures on IA and Tubing. Pressure Rose up to 30 psi on IA and 60 psi on Tubing after 1 hour. Open IA and Tubing and bleed to 0 psi. Gas returns only on IA and small stream of fluid on Tubing side. Shut well in and monitor pressures. IA pressure 30 psi and Tubing 50 psi in 30 minutes. 01 :30 - 08:30 7.00 FISH P DECOMP Spot and RlU SWS E-line Unit, RlU 7" x 5 1/2" Otis XO, Lubricator Extension, Pump in Sub, Lubricator, Wireline BOP's and Grease head. 08:30 - 10:30 2.00 FISH P DECOMP Pressure Test E-Line Equipment to 1000 psi. RIH w/3.78" Printed: 9/25/2006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/8/2006 08:30 - 10:30 2.00 FISH P DECOMP Gauge Ring Junk Basket. Initially Hung Up At 790' ELMD. Work Tool String and Fall Through. Continue to RIH to 10110' ELMD. 10:30 - 11 :30 1.00 FISH P DECOMP POOH w/ Gauge Ring. Bleed Down Lubricator, -10 psi on Tubing and Annulus. 11 :30 - 12:30 1.00 FISH P DECOMP UD Gauge Ring Junk Basket. Run Diagnostics on Chern Cutter Tool String. Found Conductivity Problem w/ WL Jars. 12:30 - 13:00 0.50 FISH P DECOMP Wait on New Jars to arrive on location. PT E-line Lub to 3000 psi. 13:00 - 13:30 0.50 FISH P DECOMP PJSM around safe handling operations with E-line Chern Cutter. M/U 4-1/2" Chem Cutter, 3.625" ID. 13:30 - 15:30 2.00 FISH P DECOMP RIH with Chern Cutter to GLM #1 at -10100'. 15:30 - 16:00 0.50 FISH P DECOMP Tie In Chern Cutter to Baker Quick Drill Log 22-Aug-06 and Tubing Tally 18- Aug-96. Tie into GLM #1 from CCL Log. Position Cutter Head and Cut Tubing at 10048' MD. Mid Joint in First Full Joint Above Packer. 16:00 - 17:30 1.50 FISH P DECOMP POOH wI Chern Cutter. Required to use jars for first 50' to pull free. 17:30 - 18:30 1.00 FISH P DECOMP UD Chern Cutter and P/U tubing punch. Cutting head in good shape, small bum hole on chem tubes. 18:30 - 19:30 1.00 FISH P DECOMP RIH with tubing punch. Tie in with Cement bond log. Punch holes from 1,795' to 1,797'. 600 psi on tubing and lA, 50 psi on OA. POOH with tubing punch. 19:30 - 20:00 0.50 FISH P DECOMP Bleed tubing and annulus from 600 psi to 430 psi. Started to get fluid back. Shut in well. 20:00 - 20:30 0.50 FISH P DECOMP Break out and UD tubing punch. 20:30 - 21 :30 1.00 FISH P DECOMP Pump 9.8 ppg Brine down the IA taking returns out the tubing through the choke manifold. 1.5 bpm at 630 psi initial circulating pressure, 530 psi final circulating pressure. Pumped 56 bbls with gas returns. Pumped 14 bbls more until clear 9.8 ppg Brine back to pits. 21 :30 - 22:30 1.00 FISH P DECOMP Monitor Well for 30 minutes. Pressure rising to 690 psi on the IA and 740 psi on the tubing. Bleed back 10 bbls. Still getting 9.8 ppg Brine mixed with Crude. 22:30 - 23:30 1.00 FISH P DECOMP M/U tubing punch tools to make second shot. 23:30 - 00:00 0.50 FISH P DECOMP RIH with tubing punch. 9/9/2006 00:00 - 00:30 0.50 FISH P DECOMP RIH with tubing punch. Tie in with previous run and punch tubing from 1,740' to 1,742'. No pressure increase on IA or tubing. 00:30 - 01 :00 0.50 FISH P DECOMP POOH with tubing punch. RID tubing punch. 01 :00 - 01 :30 0.50 FISH P DECOMP Pressure on IA 690 psi and tubing 740 psi. Open choke and bleed off gas. Pressure bled down to 0 on the tubing and 130 psi on the IA. Shut well in. Pressures rose to 150 psi on the IA and 130 psi on the tubing. 01 :30 - 02:00 0.50 FISH P DECOMP Pump 9.8 ppg Brine down the IA taking returns out the tubing. Circulate at 2 bpm at 280 psi on the IA and 160 psi on the tubing. Pumped 40 bbls getting gas returns. Pump 10 bbls more till clear 9.8 ppg brine to pits. 02:00 - 03:00 1.00 FISH P DECOMP Monitor well and allow pressures to stabilize. 310 psi on the IA and 170 psi on the tubing. 03:00 - 03:30 0.50 FISH P DECOMP Bleed off pressures, bled down to 0 psi on both sides. Open choke and IA. No flow. 03:30 - 04:30 1.00 FISH P DECOMP M/U jet cutter #1. Printed: 9/25/2006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC, DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/9/2006 04:30 - 05:00 0.50 FISH P DECOMP RIH with jet cutter #1, tie in with cement bond log. Cut tubing at 1,720'. 05:00 - 05:30 0.50 FISH P DECOMP POOH with jet cutter. 05:30 - 08:30 3.00 FISH P DECOMP UD #! Jet Cutter. Re-Tie Weak Point on E-Line Head. M/U Jet Cutter #2, C/O E-Line Crews. 08:30 - 09:30 1.00 FISH P DECOMP RIH w/ Jet Cutter #2. Tie in Cutter and Make Cut on 4-1/2" Tbg at 1415'. POOH and UD Cutter. 09:30 - 10:30 1.00 FISH P DECOMP Clrc Down IA w/ 9.8 ppg Brine at 2.5 bpm. Returns to Surface after 19 bbls pumped. Clean Fluids for first 10 bbls , afterwards crude and mixture of crude and brine. Circ a total of 47 bbls. Returns never fully clean. 0 psi on tbg and IA after circulation. 10:30 - 11 :30 1.00 FISH P DECOMP M/U Jet Cutter #3 and RIH. Cut Tubing at 1125'. POOH and UD Jet Cutter. Tbg and IA still 0 psi. 11 :30 - 13:30 2.00 FISH P DECOMP Rebuild Weak Point on E-Line Head for Drift Run. Order out E-line Jars and WL Swedge and Centrilizer. IA Pressure Up to 70 psi and Tbg Pressure at 30 psi. 13:30 - 15:00 1.50 FISH P DECOMP M/U 3.725" WL Tapered Swedge, 3.783" WL Centrilizer, CCL, Eline Jars and Weight bars. RIH and Tag Up on Jet Cut at 1125'. Make Multiple Attempts to get through at 50,60, and 70 fpm. Pick Up Clean Each Attempt. 15:00 - 15:30 0.50 FISH P DECOMP POOH w/ Drift. Inspection of Tools Showed small mark on lower nose of swedge - 2.5" in OD. P/U 3.5" LIB. 15:30 - 16:00 0.50 FISH P DECOMP CIrculate down IA and up Tubing with 9.8 ppg Brine at 2.5 bpm. Required 4 bbls to get returns to surface. Returns were crude cut brine. 16:00 - 19:00 3.00 FISH P DECOMP RIH with 3.5" LIB. Unable to get past hanger. POOH and Redress LIB. Run Back in hole and Tag Up on Tbg Cut at 800'. Attempt to work through. Tool String Stuck, can not move up or down. Inspect Line, Sheeve, and Flow Tubes to make sure surface equipment not an issue. Pull up to 700 Ibs over tool string wt. Pull Free but dragging up hole. Stuck again 50' above cut in casing connection. Work tool string. Pull Up to max safe pull three times. String still stuck. Pump on IA and up tubing to free tool string. POOH. LIB mushroomed showing slight offset in tubing cut. 19:00 - 20:30 1.50 FISH P DECOMP RID SWS unit. RID wireline lubricator and wireline BOP's. 20:30 - 21 :30 1.00 KILL P DECOMP Shut in and monitor well pressures. Pressure on the IA 180 psi, pressure on the tubing 180 psi. 21 :30 - 22:00 0.50 KILL P DECOMP Bleed pressures down to 30 psi on both sides. Initial gas returns. Started getting crude back. Shut well in. 22:00 - 22:30 0.50 KILL P DECOMP Pump down IA taking returns out the tubing through the choke manifold. 2 bpm at 220 psi. Took 7 bbls to get returns. Getting crude then crude and brine returns. Pump a total of 70 bbls of 9.8 ppg brine. 22:30 - 00:00 1.50 KILL P DECOMP Shut well in and monitor pressures. 20 psi on the IA and tubing. Climbing to 50 psi on the IA and 60 psi on the tubing. 9/10/2006 00:00 - 01 :30 1.50 KILL P DECOMP Monitor well. IA Pressure 90 psi, 100 psi on Tbg. Open choke and bleed off pressure. Pressure bled to 0 psi. Bled off gas with slight crude/brine returns. 01 :30 - 02:00 0.50 KILL P DECOMP Shut well in. Pressures building to 20 psi on the IA and tubing in 30 minutes. 02:00 - 02:30 0.50 KILL P DECOMP Pump down IA taking returns out the tubing through the choke Printed: 9/25/2006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/10/2006 02:00 - 02:30 0.50 KILL P DECOMP manifold. 3 bpm at 270 psi. Took 5 bbls to fill. Crude returns for 5 bbls followed by crude / brine returns. Pump 80 bbls till good 9.8 ppg brine back. IA and tubing pressure 0 psi. Shut well in. 02:30 - 04:30 2.00 KILL P DECOMP Monitor well. Pressures built to 110 psi on the IA and 100 psi on the tubing. 04:30 - 07:30 3.00 KILL P DECOMP Open choke and bleed off pressure. Pressure bled off immediately. Open choke fully and open IA to slop tank. No flow observed. Monitor for flow at shakers and slop tank. 07:30 - 08:00 0.50 KILL P DECOMP Pump down IA taking returns out the tubing through the choke manifold. 5.5 bpm at 560 psi. Took 4 bbls to fill. Crude returns followed by crude / brine retums. Pump 90 bbls till good 9.8 ppg brine back. IA and tubing pressure 0 psi. Shut well in. 08:00 - 09:30 1.50 KILL P DECOMP Monitor well. Pressures built to 50 psi on the IA and 50 psi on the tubing. 09:30 - 10:00 0.50 KILL P DECOMP Pump down IA taking returns out the tubing through the choke manifold. 5.0 bpm at 450 psi. Took -4 bbls to fill. Crude returns followed by crude / brine returns. Pump 20 bbl high visc sweep and chased with 47 bbls of 9.8 ppg brine. Pump till good 9.8 ppg brine back. IA and tubing pressure 0 psi. Shut well in. 10:00 - 12:00 2.00 KILL P DECOMP Monitor well. Pressures built to 80 psi on the IA and 75 psi on the tubing. 12:00 - 13:00 1.00 KILL P DECOMP Bleed Pressures to zero psi. Mix 20 bbl High Visc Sweep. Pump down IA taking returns out the tubing through the choke manifold. 5.0 bpm at 470 psi. Took -4 bbls to fill. Crude returns followed by crude / brine returns. Pump 20 bbl high visc sweep and chased with 77 bbls of 9.8 ppg brine. Pump till good 9.8 ppg brine back. IA and tubing pressure 0 psi. Shut well in. 13:00 - 15:30 2.50 KILL P DECOMP Monitor well. Pressures built to 80 psi on the IA and 75 psi on the tubing in one hour. Bleed pressures to zero through choke. Mostly gas some liquids in returns when most pressure was bled off. Shut-in and Monitor again for another hour. Pressure Built backto 85 psi on IA and 80 psi on tubing. 15:30 - 16:30 1.00 KILL P DECOMP Pressure Test Well to 1000 psi to confirm not leaking to past Casing (CMIT Tx IA). Pressure Test to 1000 psi for 10 mins. Good Solid Test. Required 7 bbls to pressure up to 1000 psi. Bleed Tubing to zero psi through Choke. IA Tracked tubing pressure. 16:30 - 17:00 0.50 KILL P DECOMP Pump down IA taking retums out the tubing through the choke manifold. 5.0 bpm at 450 psi. Took -4 bbls to fill. Crude returns followed by crude / brine returns. Pump 70 bbls of 9.8 ppg brine. Pump till good 9.8 ppg brine back. IA and tubing pressure 0 psi. Open IA through 2" to Slop Tank and Tubing through Choke to Slop tank. No visible flow of gas or liquids from either. 17:00 - 18:30 1.50 KILL P DECOMP With 2" hose from IA to Slop Tank open and Tbg open through Choke. Monitor Well. No visable signs of gas or fluid flow. 18:30 - 20:00 1.50 KILL P DECOMP Open 7" Valve on top of shooting flange to observe well. Gas breaking out of fluid and fluid level rising in BOP stack. Shut in 7" Valve. Shut in tubing side with IA open, Tubing pressure built to 60 psi. Closed IA and pressure built to 30 psi in 10 minutes on the IA. Pressure on tubing built to 70 psi. 20:00 - 21 :00 1.00 KILL P DECOMP Mix and pump 20 bbl hi-vis Safe Surf Sweep followed by 60 bbls of heated 9.8 ppg brine. Pumped down IA taking returns Printed: 9/25/2006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B~02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/4/2006 9/23/2006 Spud Date: 9/4/2006 End: 9/10/2006 20:00 - 21 :00 1.00 KILL P DECOMP out the tubing through the choke manifold. Pump 4 bpm at 260 psi. Took 5 bls to get returns. Returns were 3-4 bbls of crude followed followed by crude/brine returns. 21 :00 - 22:30 1.50 KILL P DECOMP Bleed pressures to 0 psi and shut well in and monitor well. Pressures built to 70 psi on the IA and 75 psi on the tubing. 22:30 - 00:00 1.50 KILL P DECOMP Bleed pressures to 0 psi. Shut well in. Install portable choke skid into 2" high pressure bleed line from IA to slop tank. 9/11/2006 00:00 - 00:30 0.50 KILL P DECOMP Pump 20 bbl Hi-Vis Safe Surf Sweep followed by 70bbls of 9.8 brine, down fA taking returns up the tubing through the choke manifold. 4 bpm at 260 psi. Took 7 bbls to fill. 4-5 bbls of crude returns followed by crude/brine returns. 00:30 - 02:00 1.50 KILL P DECOMP Shut well in and monitor well. Tubing pressure building to 70 psi and IA pressure building to 65 psi. 02:00 - 03:00 1.00 KILL P DECOMP Bleed pressures to 0 psi and monitor well with IA and choke manifold open. Indication of gas breaking out at gas buster. 03:00 - 03:30 0.50 KILL P DECOMP Circulate 60 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 bpm at 340 psi. Took 8 bbls to fill. 5-6 bbls of crude followed by crude/brine returns 03:30 - 05:00 1.50 KILL P DECOMP Shut well in and monitor well. Tubing pressure building to 50 psi and IA pressure building to 40 psi. 05:00 - 06:30 1.50 KILL P DECOMP Bleed pressures to 0 psi and monitor well with IA and choke manifold open. 06:30 - 07:00 0.50 KILL P DECOMP Circulate 50 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 bpm at 340 psi. Took 3 bbls to fill heavily cut crude/brine returns. 07:00 - 08:30 1.50 KILL P DECOMP Shut well in and monitor well. Tubing pressure building to 70 psi and IA pressure building to 60 psi. 08:30 - 10:30 2.00 KILL P DECOMP Bleed pressures to 0 psi and monitor well with IA and choke manifold open. 10:30 - 14:00 3.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 3 bbls brine at slowest rate possible every 10 mins keeping constant returns flowing thru choke. Crude 10-15% of returns. 14:00 - 15:30 1.50 KILL P DECOMP Shut-in and Monitor Pressures. Annulus pressure to 45 psi and Tbg Pressure to 30 psi. 15:30 - 16:00 0.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 bpm at 370 psi. Took 2.5 bbls to fill, heavily cut crude/brine returns. 16:00 - 18:30 2.50 KILL P DECOMP Shut well in and monitor well. Tubing pressure building to 40 psi and IA pressure building to 40 psi. Pressure looking like it was leveling off atter - 1 hr. Then climbed to 50 psi on the IA and 60 psi on the tubing. 18:30 - 19:00 0.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 bpm at 310 psi. Took 3 bbls to fill, heavily cut crude/brine returns. 19:00 - 21 :00 2.00 KILL P DECOMP Bleed pressure off to 0 psi. Shut in and monitor well pressures. IA built to 55 psi and tubing to 60 psi. 21 :00 - 21 :30 0.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 bpm at 290 psi. Took 3.5 bbls to fill, heavily cut crude/brine returns. 21 :30 - 23:30 2.00 KILL P DECOMP Bleed pressure off to 0 psi. Shut in and monitor well pressures. IA built to 50 psi and tubing to 55 psi. 23:30 - 00:00 0.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up Printed: 9/2512006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/4/2006 9/23/2006 Spud Date: 9/4/2006 End: 9/11/2006 23:30 - 00:00 0.50 KILL P DECOMP the tubing through the choke. Pump 4 bpm at 280 psi. Took 3 bbls to fill, heavily cut crude/brine returns. 9/12/2006 00:00 - 01 :30 1.50 KILL P DECOMP Bleed pressures to 0 psi. Shut in and monitor well. Pressure built to 50 psi on the tubing and 45 psi on the IA. 01 :30 - 02:00 0.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 BPM at 270 psi. Took 3.5 bbls to fill, heavily cut crude/brine returns. 02:00 - 03:30 1.50 KILL P DECOMP Bleed pressures to 0 psi. Shut in and monitor well. Pressure built to 70 psi on the tubing and 60 psi on the IA. 03:30 - 04:00 0.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 BPM at 270 psi. Took 3 bbls to fill, heavily cut crude/brine returns. 04:00 - 05:30 1.50 KILL P DECOMP Bleed pressures to 0 psi. Shut in and monitor well. Pressure built to 70 psi on the tubing and 60 psi on the IA. 05:30 - 06:00 0.50 KILL P DECOMP Circulate 75 bbls of 9.8 ppg brine down the IA taking returns up the tubing through the choke. Pump 4 BPM at 270 psi. Took 3 bbls to fill, heavily cut crude/brine returns. 06:00 - 07:00 1.00 KILL P DECOMP Shut-In and monitor well pressure increase to 75 psi on TBG and 70 psi on Annulus. 07:00 - 08:00 1.00 KILL P DECOMP Bleed Pressure of both the Annulus and TBG to 0 psi. Open Annulus to Slop Tank. Circulate down TBG at 5 BPM/320 psi. 08:00 - 09:00 1.00 KILL P DECOMP Shut-In and monitor well pressure increase to 70 psi on both the Annulus and TBG. 09:00 - 10:00 1.00 KILL P DECOMP Bleed off Annulus and TBG to 0 psi. Pump HiVis pill down TBG 5 BPM/160 psi. Chase w/ 20 bbls of 9.8 ppg Brine spotting the pill on the Annulus. 10:00 - 10:30 0.50 KILL P DECOMP Monitor TBG pressure while opening Annulus to Slop Tank. 10:30 - 13:30 3.00 KILL P DECOMP Pump down the TBG 2 bbls of Brine each 10 minutes. RU BHA handling equipment. 13:30 - 14:30 1.00 KILL P DECOMP Pump 100 bbls of 9.8 ppg Brine. Balance 40 bbl HiVis pill on both Annulus and TBG at 5.5 BPM/ 230 psi. 14:30 - 15:30 1.00 KILL P DECOMP Monitor well pressure build to 15 psi on TBG and 5 psi on Annulus. 15:30 - 20:30 5.00 KILL P DECOMP PU 4" DP and stand back in derrick to build pocket for standing back 3 1/8" DC. Continue monitoring well pressure build to 40 psi on TBG. Annulus left open to slop tank and visually monitored. Pockets of gas and crude burping every now and then. 20:30 - 21:30 1.00 KILL P DECOMP Bleed TBG pressure to 0 psi and reverse circulate 75 bbls of 9.8 ppg brine at 4 BPM/ 300 psi. Pumped 5 bbls before returns came to surface. Spotted 2nd HiVis balanced Pill. Discuss plan forward with town. Plan to spot a 12 ppg Weighted/ HiVis pill in upper 800' of well. Order Pill from M-I 21 :30 - 22:30 1.00 KILL P DECOMP Shut-In and monitor well pressure increase to 100 psi on both Annulus and TBG. 22:30 - 00:00 1.50 KILL P DECOMP Bleed both Annulus and TBG to 0 psi. Shut-In and monitor. 9/13/2006 00:00 - 03:30 3.50 KILL P DECOMP Continue monitoring well pressure. Pressure built to 75 psi on TBG and 50 psi on Annulus. Bleed to 0 psi on both to allow more crude and gas to migrate to surface. Pressure was allowed to build to 35 psi on Annulus and 60 psi on TBG. Bleed both TBG and Annulus to 0 psi. Shut-In and monitor pressure gain of 60 psi on TBG and 32 psi on Annulus, allow crude to swap with heavier brine. RD McEvoy Valve and RU Printed: 9/2512006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/13/2006 00:00 - 03:30 3.50 KILL P DECOMP Flow Nipple. 03:30 - 04:30 1.00 KILL P DECOMP Bleed pressure off TBG and Annulus to O. Reverse circulating 75 bbls of 9.8 ppg brine at 4 BPM/ 300 psi to displace crude thoughout TBG and Annulus. Chase with 20 bbls HiVis spacer 4 BPM/ 300 psi. Followed by 70 bbls of 12 ppg brine at 4 bpm/ 180 psi. Monitor SICP= 0 psi, SITP= O. Open Choke & Kill lines and monitor no flow. Open Blinds and Monitor well. No Flow. 04:30 - 05:30 1.00 KILL P DECOMP RIH w/3-1/8 Drill Collars, and 3 Joints of 2-7/8" Drill Pipe to 462'. Well start flowing up TBG. Monitor W/O moving pipe. Receive 2 bbl Pit Gain. Shut-In Well. 05:30 - 06:00 0.50 KILL P DECOMP Monitor Pressure increase on both TBG and 9-5/8" Annulus, 40 psi on both TBG and 9-5/8" Annulus. 06:00 - 07:30 1.50 KILL P DECOMP Continue monitoring pressure build to 70 psi on both the Annulus and the TBG. Bleed both TBG and Annulus to 0 psi. Allow and monitor pressure increase to 60 psi on both the Annulus and TBG. 07:30 - 08:00 0.50 KILL P DECOMP Bleed pressure on Annulus and TBG to 0 psi. Circulate Drill Pipe volume at 6 BPM/ 520 psi. 08:00 - 10:00 2.00 KILL P DECOMP RIH (Stripping) w/500 psi on Bag, bleed 1 bbl of fluid thru choke each 5 Jts RIH. RIH from 462' to 1300'. 10:00 - 10:30 0.50 KILL P DECOMP Circulate 10 bbls of 9.8 ppg Brine @ 2 BPM/ 500 psi to clean out influx of crude in the 4-1/2" TBG. 10:30 - 12:00 1.50 KILL P DECOMP Continue Stripping in the hole w/2-7/8" Drill Pipe F/1300' to 1760'. 12:00 - 12:30 0.50 KILL P DECOMP Circulate 37 bbls 9.8 ppg Brine @ 2 BPM/680 psi on 1/2 open choke to clean crude from 4-1/2" TBG. Shut-Down Pump and monitor Well dead. 12:30 - 13:30 1.00 KILL P DECOMP Open Bag and RIH w/o stripping from 1760' to 2226'. 13:30 - 14:00 0.50 KILL P DECOMP Close Bag and circulate 30 bbls 9.8 ppg Brine @ 2 BPM/ 690 psi w/ choke 1/2 open. Bleed pressure, open Bag, and monitor Well dead. 14:00 - 15:00 1.00 KILL P DECOMP Continue RIH F/ 2226' to 2686'. 15:00 - 15:30 0.50 KILL P DECOMP Close Bag and circulate 35 bbls of 9.8 ppg Brine @ 2 BPM/ 720 psi. Bleed off pressure, open Bag, and monitor Well dead. 15:30 - 16:00 0.50 KILL P DECOMP Continue staging in hole F/ 2686' to 3150'. 16:00 - 16:30 0.50 KILL P DECOMP Close Bag and circulate 40 bbls of 9.8 ppg Brine @ 2 BPM/ 740 psi. Bleed pressure, open Bag, and monitor Well dead. 16:30 - 17:00 0.50 KILL P DECOMP Continue RIH F/3150' to 3610'. 17:00 - 17:30 0.50 KILL P DECOMP Close Bag and circulate 40 bbls of 9.8 ppg Brine @ 2 BPM/ 780 psi. Bleed pressure, open Bag, and monitor Well dead. 17:30 - 19:00 1.50 KILL P DECOMP Continue RIH F/ 3610' to 4537'. 19:00 - 20:00 1.00 KILL P DECOMP Close Bag and circulate 40 bbls of 9.8 ppg Brine @ 2 BPMI 900 psi. Bleed pressure, open Bag, monitor Well dead. 20:00 - 21 :00 1.00 KILL P DECOMP Continue RIH F/ 4537' to 5466'. 21 :00 - 22:00 1.00 KILL P DECOMP Close Bag and circulate 64 bbls of 9.8 ppg Brine @ 2 BPMI 1000 psi. Bleed pressure, open Bag, monitor Well dead. 22:00 . 22:30 0.50 KILL P DECOMP Continue RIH F/ 5466' to 6385'. 22:30 - 23:30 1.00 KILL P DECOMP Close Bag and circulate 75 bbls of 9.8 ppg Brine @ 2 BPMI 1020 psi. Bleed pressure, open Bag, monitor Well dead. 23:30 - 00:00 0.50 KILL P DECOMP Continue RIH w/ 2-7/8" Drill Pipe F/ 6385' to 6835'. 9/14/2006 00:00 - 01 :00 1.00 KILL P DECOMP Continue RIH w/ 2-7/8" Drill Pipe F/ 6835' to 7300' Printed: 9/25/2006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/14/2006 01 :00 - 01 :30 0.50 KILL P DECOMP Close Bag and circulate 85 bbls of 9.8 ppg Brine @ 2 BPM/ 1040 psi. Bleed pressure, open Bag, and monitor Well dead. 01:30 - 02:30 1.00 KILL P DECOMP Continue RIH w/2-7/8" Drill Pipe FI 7300' to 8300'. 02:30 - 03:30 1.00 KILL P DECOMP Close Bag and circulate 96 bbls of 9.8 ppg Brine @ 2 BPM/ 1200 psi. Crude contamination in Brine was slight enough to take returns back into Pits. Bleed pressure, open Bag, and monitor Well dead. 03:30 - 04:30 1.00 KILL P DECOMP Continue RIH wI 2-718" Drill Pipe FI 8300' to 9300'. 04:30 - 05:30 1.00 KILL P DECOMP Close Bag and circulate 107 bbls of 9.8 ppg Brine @ 2 BPMI 1190 psi. Take returns into pits after crude cleared up from returns. Bleed pressure, open Bag, monitor Well dead. 05:30 - 07:00 1.50 KILL P DECOMP Continue RIH w/2-7/8" Drill Pipe FI 9300' to 10064'. 07:00 - 09:00 2.00 KILL P DECOMP Close Bag and reverse circulate 195 bbls of 9.8 ppg Brine @ 2 BPM/1760 psi. 09:00 - 09:30 0.50 KILL P DECOMP Circuate 72 bbls down the Drill Pipe @ 2 BPMl1460 psi. 09:30 - 10:00 0.50 KILL P DECOMP Monitor Well. Annulus pressure increase from 0-25 psi. Gas breaking out on surface on TBG side. 10:00 - 10:30 0.50 KILL P DECOMP Bleed off Pressure and circulate 72 bbls @ 3 BPM/ 2700 psi. 10:30 - 11 :00 0.50 KILL P DECOMP Monitor well. Annulus pressure increased from 0-12 psi. Gas still breaking out on TBG side. 11 :00 - 11 :30 0.50 KILL P DECOMP Bleed pressure and circulate 50 bbls @ 3 BPMI 2800 psi taking retums through Annulus back to pits. 11 :30 - 12:30 1.00 KILL P DECOMP Monitor Well. Annulus pressure increase from 0-20 psi. Gas still breaking out on TBG side. 12:30 - 13:00 0.50 KILL P DECOMP Bleed pressure and spot a SafeSurf Pill outside of DP. 13:00 - 13:30 0.50 KILL P DECOMP Monitor Well. Annulus pressure increase from 0-8 psi. Minimal gas on TBG. 13:30 - 15:30 2.00 KILL P DECOMP Shut Bag and displace Pill from Wellbore wI 200 bbls at 1.3-3 BPM/580-2510 psi. 15:30 - 16:00 0.50 KILL P DECOMP Open Well and monitor. Annulus pressure increase from 0-2 psi. No Gas on TBG. 16:00 - 17:00 1.00 KILL P DECOMP Shut Bag and circulate 130 bbls @ 3 BPMl2650 psi. 17:00 - 17:30 0.50 KILL P DECOMP Open Well and monitor pressure. Well dead, 0 pressure on Annulus and 0 pressure on TBG. 17:30 - 00:00 6.50 KILL P DECOMP POOH and lay down 2-7/8" Drill Pipe from 10,128 to 4200'. Stop and visually observe well each 1000' POOH. Well is stable and dead. 9/15/2006 00:00 - 01 :30 1.50 KILL P DECOMP Continue POOH wI 2-7/8" Drill Pipe from 4290' to 1979'. 01 :30 - 02:30 1.00 KILL P DECOMP Circulate 25 bbls long way @ 3 BPM/1040 psi. Close Bag and circulate down DP and out the 9-518" Annulus. Monitor returns to see percentage of Crude in Brine. 02:30 - 05:30 3.00 KILL DECOMP Continue POOH wI 2-718" Drill Pipe from 1979'. 05:30 - 06:30 1.00 CLEAN DECOMP RD and clear Rig Floor. 06:30 - 07:00 0.50 BOPSU DECOMP Set TWC Valve. 07:00 - 08:00 1.00 BOPSU DECOMP Change out Pipe Rams to 3-1/2" x 6" variables. 08:00 - 08:30 0.50 BOPSU DECOMP RU to test BOPE 08:30 - 13:00 4.50 BOPSU DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. Test witnessed by Chuck Sheave wI AOGCC, Doyon Toolpusher, and BP WSL. Test #1- Lower Pipe Rams wI 4" Test #2- Lower Pipe Rams wI 4-1/2' Test #3- Hydrill, HCR Choke, HCR Kill, TlW Test #4- Manual Kill Valve, Manual Choke Valve, Dart Valve Printed: 9/25/2006 11 :25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: RD BOPE Testing Equipment Pull TWC Valve MU Spear Assemby and BOLDS. Pull HGR to Floor @ 50K Up Wt. MU Circulating Head and CBU @ 9 BPM/660 psi. Monitor Well dead. POOH w/1 ¡t TBG. Control Line was not cut. Unsuccessfully attempt to part by pulling. Manually cut Control Line and POOH wi 18 Jts plus 21.36' of Jt #19 wi 7 Band POOH. RD TBG Equipment and clear Rig Floor. MU Rope Spear. RIH to 529' and work on Fish. POOH wi Fish. Retrieved 1058' of Control Line and 8 SS Bands. RIH wi Rope Spear and establish parameters of 47K upl 47K down. Tag TBG stump @ 799' and work on Fish. CBU @ 8 BPMI 250 psi to clean well bore of any Crude. Returns only had trace amount of Crude. POOH wi Rope Spear and lay down fish. Retrieved 540' of Control Line. UD BHA. Clear Rig Floor and install Wear Ring. PU and MU 8-1/8" WashPipe Assemby PU Drill Collars and RIH. Establish Parameters (PU Wt-75K, SO Wt-75K, RT-72K, TO-2K). Tag CMT @ 817'. Displace Well to 8.6 ppg FloPro @ 8 BPM/ 200 psi. Mill Control Line and CMT f/817' to 850' @ 40-50 RPM, 7 BPM/200-270 psi, wi 2-3K TO, 19K WOB. Continue milling on Control Line and Annular CMT f/ 850' to 900' @ 80 RPM, 8 BPMI 300 psi, 8K TO, 19K WOB POOH wi WashPipe/ Burnshoe Assembly. Mill wore out. Teeth 2/3 gone. Indications show that 4-1/2" TBG is off to one side, and Mill is burning through TBG. Recovered part of TBG Collar plus various pieces of TBG in Boot Basket. DECOMP Clear Rig Floor. DECOMP RIH wi BurnShoe Assembly to 900'. DECOMP Establish Parameters of PU Wt- 77K, SO Wt- 77K, RT Wt- 75K. Mill on Annular CMT fl 900' to 933' w/4 BPMl140 psi, 12-15K WOB, 2-10K TO, 50 RPM. DECOMP CBU and displace FloPro Mud to 9.8 ppg Brine @ 8 BPM/ 240 psi. 13:00 - 13:30 0.50 BOPSU P DECOMP 13:30 - 14:00 0.50 BOPSU P DECOMP 14:00 - 16:00 2.00 CLEAN P DECOMP 16:00 - 16:30 0.50 CLEAN P DECOMP 16:30 . 19:00 2.50 CLEAN P DECOMP 19:00 - 20:00 1.00 CLEAN P DECOMP 20:00 - 21 :00 1.00 CLEAN P DECOMP 21 :00 - 21 :30 0.50 CLEAN P DECOMP 21 :30 - 23:30 2.00 CLEAN P DECOMP 9/16/2006 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 01:00 0.50 CLEAN P DECOMP 01 :00 - 02:30 1.50 CLEAN P DECOMP 02:30 - 03:00 0.50 CLEAN P DECOMP 03:00 - 05:00 2.00 CLEAN P DECOMP 05:00 - 07:00 2.00 CLEAN P DECOMP 07:00 - 07:30 0.50 CLEAN P DECOMP 07:30 - 12:00 4.50 CLEAN P DECOMP 12:00 - 00:00 12.00 CLEAN P DECOMP 9/17/2006 00:00 - 02:30 2.50 CLEAN P DECOMP 02:30 - 03:00 03:00 - 07:30 07:30 - 14:30 0.50 CLEAN P 4.50 CLEAN P 7.00 CLEAN P 14:30 - 15:00 0.50 CLEAN P Test #5- Choke Valves 1, 12, 13, 14 Test #6- Blinds, Choke Valves 9, 11 Test #7- Choke Valves 5,8, 10, Upper IBOP Test #8- Choke Valves 4, 6, 7, Lower IBOP Test #9- Choke Valve 2 Test #10- Choke Valve 3 Accumulater Test- 3,000 psi Starting Pressure; 1,900 psi After Actuation, First 200 psi in 15 seconds, Full Pressure in 1 Minute 9 Seconds. 5 Nitrogen Bottles at 2,200 psi. Printed: 9/25/2006 11 :25:36 AM '. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/17/2006 15:00 - 17:00 2.00 CLEAN P DECOMP POOH w/ Burnshoe Assembly and TBG Fish inside WashPipe. 17:00-21:00 4.00 CLEAN P DECOMP PJSM on handling TBG from inside WashPipe. Call for TBG Cutter. RU and pull 113' of TBG and Control Line from WashPipe. 21 :00 - 21 :30 0.50 CLEAN P DECOMP Clear and clean Rig Floor. 21 :30 - 00:00 2.50 CLEAN P DECOMP PU new Burnshoe and RIH on 12 Jts Wash Pipe and 12 DC. 9/18/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Continue RIH to 929'. Tag Junk @ 929'. Displace Wellbore back to FloPro Mud @ 6.5 BPM/ 140 psi. 00:30 - 03:00 2.50 CLEAN P DECOMP Establish parameters of 77K PU wt, 77K SO wt, mill from 933' to 941' (WOB- 10-15K, TO- 2-9K, 7 BPMI 270 psi). Milling was very erratic and stopped at 941 '. 03:00 - 03:30 0.50 CLEAN P DECOMP CBU and displace Well back to brine for trip. 03:30 - 07:00 3.50 CLEAN P DECOMP POOH wi Burnshoe/WashPipe Assembly. Recover 5# Metal in Boot Baskets. Mill condition: all teeth missing, bottom of Mill wore flat, 3 teeth recovered in Boot Basket. 07:00 - 08:00 1.00 CLEAN P DECOMP C/O Saver Sub and Service Rig. 08:00 - 10:30 2.50 CLEAN P DECOMP MU and RIH wi Flat Bottom Rotary Junk Mill on Wash Pipe Assembly. Tag Junk @ 903'. 10:30 - 11 :30 1.00 CLEAN P DECOMP Displace Brine in Wellbore to FloPro Mud @ 8 BPM/240 psi. Obtain Parameters of 77K PU wt, 72K SO wt. 11 :30 - 13:00 1.50 CLEAN P DECOMP Wash and work over Junk @ 903' to Bottom of 941'. 13:00 - 00:00 11.00 CLEAN P DECOMP Continue Milling operation from 941' to 1034' w/10-15K WOB, 45-50 RPM, 4-5.5 BPM/180-300 psi. 9/19/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Continue Milling Annular CMT fl 1034' to 1062' wi 10-15K WOB, 2-12K TO, 45 RPM, 4 BPM/180 psi. Erratic torque increased and drilling stopped. 03:00 - 03:30 0.50 CLEAN P DECOMP Displace FloPro Mud from Well bore w/9.8 ppg Brine. 03:30 - 05:30 2.00 CLEAN P DECOMP POOH w/ WashPipel Milling Assembly. 05:30 - 06:00 0.50 CLEAN P DECOMP Clean and Clean Rig Floor. C/O Mill. 06:00 - 08:00 2.00 CLEAN P DECOMP RIH w/8 1/8" Wash Pipe Assembly. Tagged Tbg Stump at 903' Obtain Parameters, P/U 77,000# S/O 78,000# R/T 75,000# Continue RIH to 1,054 Tagged Up on Debris 08:00 - 08:30 0.50 CLEAN P DECOMP Swap Fluid to 8.7 ppg Flo-Pro , Obtain SPRs 08:30 - 19:00 10.50 CLEAN P DECOMP Continue to Mill Cement f/1 ,062', WOB 8-10,000#,2-12,000 ft-Ibs Torque, 45 rpm, 4 bpm, 180 psi. Milled to 1,101' 19:00 - 19:30 0.50 CLEAN P DECOMP Pump 10 bbl Hi-Vis Sweep, Followed by Brine at 8 bpm, 350 psi. 19:30 - 21 :00 1.50 CLEAN P DECOMP Monitor Well POOHf/1,101'. 21 :00 - 00:00 3.00 CLEAN P DECOMP 4.5" Tubing Wedged into Wash Pipe. 160' of 4.5" Tubing Recovered and Layed Down. One Jt of 4.5" Had Tubing Collar Cut approx 30% Around. Rotary Shoe Was Packed With What is Believed to be 9 5/8" Casing. One Piece of The Suspect 9 5/8" Was Recovered From Boot Basket. 9/20/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue to UD Tubing From Inside Wash Pipe. Flush BOP Stack of Metal w/Circulation Sub. 01 :30 - 02:00 0.50 CLEAN P DECOMP RIU to Test 9 5/8" x 133/8" Casing. 02:00 - 02:30 0.50 CLEAN P DECOMP Test 9 5/8" x 133/8" Casing to 1 ,000 psi. 02:30 - 03:00 0.50 CLEAN P DECOMP Rig Down Blow Down Test Equipment. 03:00 - 03:30 0.50 CLEAN P DECOMP B/O Rotary Shoe. Fish Inside. 03:30 - 06:00 2.50 CLEAN P DECOMP RIH wi 81/8" Wash Pipe Assembly. Tagged Soft Cement at 1 ,096'. P/U Weight 77,000#, S/O 77,000#, Rotating 73,000#. 06:00 - 06:30 0.50 CLEAN P DECOMP Swap Fluid to 8.7 ppg Pro- Flow Mud. 7 bpm, 240 psi. Printed: 9/25/2006 11 :25:36 AM '. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/20/2006 06:30 - 22:00 15.50 CLEAN P DECOMP Continue Milling Cement and Junk f/1, 1 01' t/1 ,185' With 4-10,000# wob, 45 rpm, 2-5,000 ft-Ibs Torque, 4 bpm, 140 psi. 22:00 - 22:30 0.50 CLEAN P DECOMP Pump 10 bbl Hi-Vis Sweep, Followed by Sea Water at 8 bpm, 250 psi. 22:30 . 00:00 1.50 CLEAN P DECOMP POOH f/1 ,185' 9/21/2006 00:00 . 01 :30 1.50 CLEAN P DECOMP POOH, Wash Pipe Had 4.5" Tubing Wedged Inside of Wash Pipe Approx 80'. With Serveral Pieces of 9 5/8" Csg and Control line. Tubing That Was Recovered Was Sliced With 1/3 Cut Away. 01 :30 - 02:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 02:00 . 02:30 0.50 CLEAN P DECOMP P/U Stack Washing Sub, Flush Stack Out. 02:30 - 04:00 1.50 CLEAN P DECOMP P/U Shoe and M/U Wash Pipe. RIH w/4 stds 6 1/4" DC 04:00 - 04:30 0.50 CLEAN P DECOMP RIH to 680'. 04:30 - 05:30 1.00 CLEAN P DECOMP Cut and Slip Drilling Line. Service Top Drive. 05:30 . 06:00 0.50 CLEAN P DECOMP RIH f/680' to 1,185'. 06:00 - 06:30 0.50 CLEAN P DECOMP Displaced Well From Sea Water Tripping Fluid to Flo-Pro Mud at 7 bpm and 240 psi. 06:30 - 16:30 10.00 CLEAN P DECOMP Continue Milling f/1,185' to 1,224', WOB 5-15,000#, 50 rpm, 2-10,000 ft-Ibs, 4 bpm, at 120 psi. 16:30 - 17:00 0.50 CLEAN P DECOMP Pumped 10 bbl Hi-Vis Sweep 2X B/U, Displaced Well to Sea Water at 9 bpm and 300 psi. 17:00 - 18:30 1.50 CLEAN P DECOMP POOH f/1 ,224' to Wash Pipe. 18:30 - 19:30 1.00 CLEAN P DECOMP Fish In Bottom Jt of Wash Pipe, Unable to Pull Out of Wash Pipe, UD it. P/U it M/U New Shoe Stand Back Wash Pipe. 19:30 - 20:00 0.50 CLEAN P DECOMP M/U Stack Washing Sub, Flush Stack. 20:00 - 21 :00 1.00 CLEAN P DECOMP Attempt to Pull Wear Ring. Unable to Retrieve, Unable to Latch into Wear Ring. 21 :00 - 21 :30 0.50 CLEAN P DECOMP M/U Stack Washing Sub, Flush Stack. 21 :30 - 22:30 1.00 CLEAN P DECOMP Attempt to Pull Wear Ring. Unable to Retrieve Due to Damaged Edge of Retrieval Slot. 22:30 - 23:00 0.50 CLEAN P DECOMP Flush Choke and Kill Lines Washing Any Metal Out of HCR Profile. 23:00 - 00:00 1.00 CLEAN P DECOMP Test Choke Manifold to 250 psi Low Test and 3,500 High Test. 9/22/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Top of wear ring damaged, can not "J" into ring for retieval. P/U M/U 9 5/8" CSG Spear w/8.681 Grapple and One it of 4" HT-38 Drillpipe. RIH Speared into Wear Ring and Pulled it to Rig Floor UD Wear Ring and 1 it Drill Pipe. 00:30 - 01 :00 0.50 CLEAN P DECOMP Set Test Plug and R/U to Test BOPE. 01 :00 - 05:30 4.50 CLEAN P DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Lou Grimalde. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Hydril, HRC Choke, HCR Kill, Upper IBOP Test #2- Manual Choke, Manual Kill, Lower IBOP Test#3-ChokeValves 1,12,13,14 Test #4- Varible Pipe Ram 3.5"x 6" Test #5- Blinds, Choke Valves 9, 11. Test #6- Choke Valves 5,8,10, TIW Test #7- Choke Valves 4,6, 7, Dart Valve Test #8-Choke Valve #2 Test #9- Choke Valve 3 Test #10- 4.5" TubingTest Jt Printed: 9/25/2006 11 :25:36 AM '. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/22/2006 01 :00 - 05:30 4.50 CLEAN P DECOMP Accumulater Test- 3,000 psi Starting Pressure, 1,850 psi After Actuation, First 200 psi in 16 seconds, Full Pressure in 1 Minute 15 Seconds. 5 Nitrogen Bottles at 2,350 psi. 05:30 - 06:00 0.50 CLEAN P DECOMP RID BOP Test Equipment, Blow Down Surface Lines. 06:00 - 06:30 0.50 CLEAN P DECOMP Install Wear Ring. 06:30 - 07:00 0.50 CLEAN P DECOMP P/U Joint 8 1/8" Wash Pipe, Back Out Shoe and Clean Out Junk Basket 07:00 - 10:00 3.00 CLEAN P DECOMP RIH w/8 1/8" Wash Pipe Assembly to 1,200' 10:00 - 11 :30 1.50 CLEAN P DECOMP RlU to Test. Bleed Down 133/8" Annulus. Test 9 5/8" Csg to 500 psi While Monitoring Annulus. Test OK, no increase of pressure on any annulus. 11 :30 - 12:00 0.50 CLEAN P DECOMP Decesion made to suspend operations on well. Prepare Pits for Change Over to 9.8 ppg Brine. 12:00 - 13:00 1.00 CLEAN P DECOMP PJSM With Rig Crew and Truck Drivers,Spot Trucks, Displace Well To 9.8 ppg Brine. Blow Down Surface Lines. 13:00 - 15:00 2.00 CLEAN P DECOMP POOH and UD Drill Collars and Wash Pipe. 15:00 - 15:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 15:30 - 17:00 1.50 CLEAN P DECOMP M/U Running Tool, Made Dummy Run Through BOP stack, M/U Fast Drill and RIH w/Same. Set at 800' Top and 804' Bottom. 17:00 - 18:00 1.00 CLEAN P DECOMP RlU to Test Fas- Drill, Weight Up Brine to 9.8 ppg. Bleed Annulus. 18:00 - 19:00 1.00 CLEAN P DECOMP Test Fas-Drill to 2,500 psi. RID Test Equipment. 19:00 - 19:30 0.50 CLEAN P DECOMP Circulate and Condition Brine, Surface to Surface. 8 bpm, 200 psi. 19:30 - 20:30 1.00 CEMT P ABAN RlU Cementers, PJSM with Rig Crew and Cement Crew. Pumped 6 bbl Arcticset 15.7ppg Balanced Cement Plug, From 800' to TOC at 725'. 20:30 - 21 :00 0.50 CEMT P ABAN POOH to 622' Reverse Circulate 80 bbls at 8 bpm, 620 psi, Blow Down Cement Lines, RID Cementers. 21 :00 - 23:00 2.00 TA P ABAN POOH UD Drill Pipe and RID Fas Drill Running Tool. RIH w/3 stds DP, POOH UD Same. 23:00 - 00:00 1.00 TA P ABAN Pull Wear Ring RlU to Run 4.5", L-80, 12.6#, NSCT Kill String. 9/23/2006 00:00 - 01 :30 1.50 TA C ABAN Continue to Rig Up to Run 4.5",12.6#, L-80, NSCT Tubing Kill String. 01 :30 - 02:00 0.50 TA C ABAN Service and Inspect Top Drive. 02:00 - 03:30 1.50 TA C ABAN P/U and Run 4.5", 12.6#, L-80, NSCT Tubing Kill String. Set Kill String at 636'. Kill String Tail pipe Consists of W-Ieg, Pup Jt, XN Nipple, Pup Jt, XO, Tail Pipe Lenght 22.77'. 03:30 - 04:00 0.50 TA C ABAN Circulate Annular Volume, 35 bbls At 7 bpm, 45 psi, BID Surface Lines, 04:00 - 05:00 1.00 TA C ABAN Land Hanger RILDs. 05:00 - 05:30 0.50 TA C ABAN Reverse Circulate 2xHole Volume 72 bbl. 05:30 - 06:30 1.00 TA C ABAN Set and Test TWC to 1,000 psi from Below. Test Failed, Re-Torqued LDS, Re-Tested, Test Failed. 06:30 - 09:00 2.50 TA C ABAN RlU Lubricator Extension, DSM, Pull TWC 09:00 - 10:00 1.00 TA C ABAN Screw into Hanger wlLanding jt, BOLDS, Pull Hanger to Floor. 10:00 - 11 :00 1.00 TA C ABAN Replace Seal Element, and Dress Upper Plate x2. 11:00 -13:30 2.50 TA C ABAN Open Ram Doors on Variables to Inspect and Retrive Junk, Clean Metal From Ram Cavities. Clean Well Head Profile, Land Hanger, RILDS, Nipple Up Ram Doors. Printed: 9/2512006 11 :25:36 AM .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: B-02A B-02A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/4/2006 Rig Release: 9/23/2006 Rig Number: Spud Date: 9/4/2006 End: 9/23/2006 13:30 - 14:30 1.00 TA C ABAN Set TWC Test to 1,000 psi From Below 3,500 psi from Above. Blow Down Surface Lines and Rig Down. 14:30 - 15:30 1.00 TA C ABAN Nipple Down BOPE. 15:30 - 16:30 1.00 TA C ABAN Nipple Up Adapter Flange and Valve Assembly. 16:30 - 18:00 1.50 TA C ABAN Test Adapter Flange and Valve Assembly to 5,000 psi for 30 minute Tests. 18:00 - 19:00 1.00 TA X WAIT ABAN Waiting On DSM to Pull TWC. 19:00 - 20:00 1.00 TA C ABAN RlU DSM Lubricator, Pull TWC, RID DSM 20:00 - 21 :00 1.00 TA C ABAN RlU Little Red to Freeze Protect Well, PJSM w/Rig Crew and Little Red Personnel. Pump 20 bbl Diesel at 2 bpm with 600 psi. 21 :00 - 21 :30 0.50 TA C ABAN U- Tube Well. 21 :30 - 22:00 0.50 TA C ABAN Blow Down Surface Lines, RID Lines in Cellar, Set BPV and Tested to 1,000 psi. 22:00 - 00:00 2.00 TA C ABAN Removed Double Annulus Valve, Secure Well. Rig Release at 00:00 9/23/2006 Printed: 9/25/2006 11 :25:36 AM RECt:.\veLl . STATE OF ALASKA . OCI 0 420U:i REP~~~KA ¿'~ ~~~~~~S:~A~~N~~~::iiarJ~ ;;;h~;;:~ Cumlnission 1. Operations Performed: Repair Well 0 Pluç PerforationsD Stimulate 0 OtherŒJSecure Well Abandon 0 Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD 196-1110 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20066-01-00 7. KB Elevation (ft): 9. Well Name and Number: 68.40 B-02A 8. Property Designation: 10. Field/Pool(s): ADL-028310 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12283 feet true vertical 9075.0 feet Plugs (measured) Baker Quickdrill @ 10124' (08/22/2006) Effective Depth measured 10149 feet Junk (measured) None true vertical 8444.0 feet Casing Length Size MD TVD Burst Collapse STRUCTURAL 107 30" 157.5# B Grade 28 - 135 28.0 - 135.0 880 CONDUCTOR 2281 20" 91.5# H-40 27 - 2308 27.0 - 2308.0 1490 470 :IRCUL STRING 2166 16" 65# K-55 26 - 2192 26.0 - 2192.0 1640 630 SURFACE 4520 13-3/8" 68# K-55 25 - 4545 25.0 - 4323.0 3450 1950 PRODUCTION 1944 9-5/8" 40# N-80 24 - 1968 24.0 - 1968.0 5750 3090 PRODUCTION 412 10-3/4" 55.5# K-55 1968 - 2380 1968.0 - 2380.0 6450 4020 PRODUCTION 3283 9-5/8" 47# N-80 2380 - 5663 2380.0 - 5196.0 6870 4760 LINER 3920 7" 29# N-80 6465 - 10385 5774.0 - 8613.0 8160 7020 LINER 2116 4-1/2" 12.6# 13Cr80 10167 - 12283 8458.0 - 9075.0 8430 7500 Perforation depth: Measured depth: 10400-10410,11920-11940, 11960·11970,12012-12032, 12090-12110, 12125-12165 True vertical depth: 8623-8630,8992-8995,8999-9000,9008-9011, 9020-9024, 9027-9035 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 22 - 10171 4-1/2" AVA DW RETR Patch @ 10386 - 10422 AVA RETR Patch Packers & SSSV (type & measured depth): 9-5/8" BKR Packer/Tieback @ 5465 7" BKR S-3 Packer @ 10115 7" TIW PKR/Tieback @ 10167 with Seal Assy 7" TIW S-6 PKR/Tieback @ 10174 4-1/2" HES HXO SSSV Nipple @ 2204 12. Stimulation or cement squeeze summary: ,";/" ". ,.~. Intervals treated (measured): ~ ..",.,}) n () ,,' fe.} Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaae Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl CasinQ Pressure Tubing Pressure Prior to well operation: SI 0 0 --- 0 Subsequent to operation: SI 0 0 -- 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD Copies of Logs and Surveys run _ 16. Well Status atter proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWaJtne R. Schnorr ~ " Title Petroleum Engineer Signature ~~...- ~ ¿,y -~ Phone 564-5174 Date 10/3/06 .~~,..~. .,,,~ ......., '" ,''''' . gr !,. \) L.f \f iP LUUU Form 10-404 Revised 4/2004 ORIG NAJ ¡ i.., . . B-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/04/2006 TIIIO/OOIOOO = 110/10017/0/0. Temp = SI. Bleed WHPs to 0 (pre RWO). Tubing pressure increased 50 psi overnight. lAP increased 40 psi overnight. Tubing & IA FLs near surface. Bled lAP to 0+ psi in 3 hrs, 5 min (all gas). Bled Tubing pressure to 0+ psi in 2 hrs, 35 min (all gas). SI, monitored for 30 min each. No change in pressures. Bled OAP to 0 psi in 10 min (all gas). SI, monitored for 30 min. OAP increased to 0+. Final WHPs = 0+10+10+1010. 09/04/2006 PULL BPV , RIG MOVED ON WELL 09/03/2006 TIIIOIOO/OOO=360/360/201010 Temp=SI Bleed WHPs to 0 psi (pre-rig). TBG & IA FLs near surface. Bled lAP from 360 psi to 260 psi in 3 hours by bleeding off the gas then shutting in bleed every 15 minutes to let gas swap out with fluid. Bled TBGP from 360 psi to 260 psi in 3 hours the same way, gas then fluid, shut in, let swap out then continue. Bled back a total of 6 bbls to slop trailer. Monitor for 1 hour while grader preps location for rig. TBGP increased to 350 (90 psi gas cap) & lAP remained unchanged. Swapped TBG & IA bleed to gas buster tank #029. Bled TBGP (350 psi) & lAP (260 psi) simultaneous to 60 psi in 4.5 hours (3 bbls returned). Bled OAP from 20 psi to 0 psi in 15 minutes. Final WHPs=60/60/01010 09/03/2006 T/I/O=600/52010 Load tbg w 9.8 brine (Pre RWO) Pump remaning xx bbls 9.8 Brine down tbg taking returns up IA to B-01 FL, freeze protect B-01 FL w. 7 bbls neat 85 bbls crude FWHP= 300/30010 09/02/2006 TIIIOIOO=010/60/0 CMIT Tx IA to 1000 psi. (PASS) Load TBG & IA w. 9.8# Brine. (Pre RWO) Pumped 7 bbls of neat meth and 200 bbls of 9.8# brine down TBG, taking returns from IA, down jumper line to well # 1. ***CMIT TxlA. Pressured up TBG & IA w. 18.5 bbls 9.8# Brine TBG and IA lost 20/20 psi in the first 15 min, and 010 psi in the second 15 Min. TBG and IA lost a20/20 psi in 30 Min. Final WHP's=400/400/2010 08/31/2006 TIIIOIOO/OOO = 0/010/010 Temp = SI CMIT TxlA Loaded IA w/105 bbfs 65* crude. Job postponed. FWPs = 010/0/0 08131/2006 TII/OIOO/OOO=1 0/1 0/1 011010. Temp.=SII. WHP'S. (Post bleed). TP increased 10 psi overnight. lAP increased 10 psi overnight. OAP increased 10 psi overnight. OOAP and OOOAP no change overnight. (AL line and FL are disconnected from well and blinded at lateral valve). 08/30/2006 T/I/OIOOIOOO=330/350/70/0/0. Temp=SI. Bleed WHP's to 0 psi. (Pre-RWO). TBG & IA FL's unreadable. Bled TP & lAP to 0 psi in 6 hours. Bled OAP from 70 psi to 0 psi in 1 hour. No fluid was returned during bleed's. Final WHP's=OIOIOIOIO. 08/29/2006 TIIIOIOOIOOO = 330/340/?10+/? Temp = SII. No AL to well. WHPs and FLs (pre-rig). TBG FL @ 636' (8 bbLs). IA FL @ 3692' (200 bbLs). 08/22/2006 WELL SHUT-IN ON ARRIVAL. TIIIO/OO = 275/210/100/0 SHOT 2 STRAND 80 GRAIN, 12' STRING SHOT OVER INTERVAL 10,037-10,049 FT. SHOT TUBING PUNCHER FROM 10010' -10012'. SET 4-1/2" BAKER QUICKDRILL AT 10124' MID ELEMENT. ***JOB COMPLETE*** Page 1 . . B-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/22/2006 T/l/OIOOIOOO = 400/1501010/NA - Load IA and TBG w/9.8# Brine (Pre RWO) - Pumped 5 bbl meth spear followed by 60 bbls 9.8# brine and 2 bbl meth cap. Pumped 5 bbls meth followed by 200 bbls 9.8# brine and 2 bbl meth cap. FWP's = vac/80/10010/NA 0812112006 T/I/OIOO/OOO = 400/3201010/NA - Load IA and TBG w/9.8# Brine. (RWO Prep) Bleed gas cap off IA. 08/16/2006 T/IIO/OOIOOO= 300/300/80/0/na. WHPs TBGP & FL (pre - Fasdrill). TBG is cut @ 799', FL appears to be 1500' (23 bbls). 08/12/2006 **** WELL SHUT IN ON ARRIVAL *** (PRE CIBPI RWO) RAN 3.80 LIB TO 773' SLM SHOW 3.25 OPENING. DRIFT W/3.0 SWAGE TO 10,200' SLM. DRIFT WI 3.625 SWAGE AND 3.625 G. RING. TO 10,200' SLM. ***LEFT WELL 811*** PAD OP NOTIFIED 08/10/2006 T/IAlOAlOOA = SIIOIOIO (Pre-Rig Workover Inspection) PPPOT-IC = PASSED PPPOT-T = PASSED Bled inner casing void to 0 psi. Tighten Rockwell style lockdown pins. Energized "Y" seals with (6) sticks of Cameron packing. Rigged up test equipment, pumped until clean fluid returns were achieved. Tested void to 3,800 psi. for 30 mins. - Passed. Bled tubing hanger void to 0 psi. Functioned/Torqued lockdown screws to 550 ftllbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 5,000 psi. for 30 mins. - Passed. 08/06/2006 T/IIO/OOIOOO=650/1000/0/0/0 Temp=S/I (Load & Kill TBG. w/9.8# brine) Bleed gas cap off IA. Pump 5 bbls neet followed by 60 bbls 9.8 Ib brine down IA @ max rate.& 2 bbl meth cap. Pump 200 bbls 9.81b brine down tbg @ 5 bpm. Bled what little gas there ws on IA off down to 0 psi. FWHP's=OIOIO/O/O 08/05/2006 T/I/OIOOIOOO=650/100010/010 (Load & Kill tbg w/9.8# brine.) Load fluids, Rig up, bleed IA gas cap off. 08/05/2006 T/I/O=600/60010 Pumped 97 bbls neat meoh down tbg for injetivity test FWHP=1050/120010 FLUIDS PUMPED BBLS 1 PT Surface Equipment 135 Neat Methanol 190 Crude 811.5 9.8# Brine 1137.5 TOTAL Page 2 . . 0, .-"'"""'\ '\ SAFEr' NOTES; 4-1fl- Qi"''-E LIR WB.l SD1RKO TÆE" 7-1/16"CAMBtON B-02A ŒF WHPSTOa< sen, 9-518- CSG (NOr SHOW". a.o walJ-lEADoo fJCBIOY waLBOREBB..OW 9- SS- f4.LOUT WINDOW NOr ON ACTIA TOR- BAKeR DAGRAM. WB..L" 70 oæ @ 10725'. KB. B.EV - 66.66' - L SF. B.EV = 40.57' . ~ KOP= 275G' 1988' 9·M!- X 10.314- XO I Max Anallt = 82@10879' I"'"-' 2192' 16" CIQJ.A TION STRI'G DalumMD" 10983' . 22Ø4' 4.112" HES HXO SSSV ~. 0 = 3.813" I DelumTVD .. 8800' SS .4 -- L. 2308' 20- CSG, 94/133#. H-4OII(-55 -' 2380' 10-314" X 9-518" XO I 110.314" CSG, 55.5#, K-55, .0925 tJpf, ID =9.76" 2380' r 113-3/8" CSG, 68#, K55. 0 = 12.416" 4545" ~ .. GAS LFTMANIRLS Minimum I) = 2.441" @ 10386' I ST M> ND œv TYÆ VLV LATCH FORT DATE 4-112" AVA DWP RETR. PATCH 6 2f1T7 2969 16 K8G-2-LS [NY SI'M 08If11102 ""ïi 5 5449 5029 39 K8G-2-LS [NY BTM 08If11102 4 7466 6432 42 K8G-2-LS SI'M I-! 3 8776 7378 -43 K8G-2-LS BTM 2 9510 7915 -43 K8G-2-LS SI'M 19-518" X r BKR R<RI TIEBACK, ID .. 7.50" 5465' t-- 1 10078 8323 -43 K8G-2-LS SI'M 19-518" X 1" BKR LNR HGF\, ID = 6. 18" 5479' t-- I I 9-518" f4.LOtJI' WNX>W 19-51S' CSG. 47#. No8a. ID" &.681" 5663' I-- !te63' - 5703' ( OFF WHlFSTOCK) I b' fc ch Holes, . I 10104' 4-112" HEB X NP, ID= 3.813" - ðO/O-¡oo/,t 7Íf IÞ'l8 fit! ,.. g ~ 10115' rx 4-112" BKR8-3P1<R,ID=3.875" I I /O/.,f,/ý BI<\~ Q,,:otÞ..:1J ... i1 10138' 4-112" HEB X NIP. D= 3.813" I I 10159' 4-112-H8S XN~, 0-3.725" J 7" X 4-1/'Z' TlW1EBACK PI<R WI SEAL ASSY 10167' I 4-1fl"1BG. 12.8#, Loo, .0152 blJf, D" 3.958" 10169' ~ 10171' 4-112"WLEG. D" 3.958" I ~ 17" X 4-112' TW $-6 R<M1IÐACK, D- 3.850" H 10174' I ~ I TIW D1H UN~ ....NGER. D - 3.922" 10185' I7"LNR,29t#.13-CR-80. .0371bpf, D.. 6.164" 10385' I ..oil .. I 10386' 4-112" AVA DIII'REm. PA1CI-\ 0=2.441" I TOTAL LSIIGTH- 311' T (08l17/W) ~TION SUMtJARI' REF lOG: AWS BI-CS 07fl9196 ANGI.EATTOP~ 48@10400' I PlJTD 12180' I IItIte: Refer to A'oducton DB for hlslDrical carl data SIZE SA' INTERVAL Oþn/Sqz DATE 'Z' 4 10400 - 10410 C œ/171f1T Z' 4 11920-11940 0 10101199 H18' 4 11960 - 11970 0 031251f1T 2-1/8 4 12012- 12032 0 09129196 1.56" 4 12040 - 12050 S œlO1l96 'Z' 4 12090 - 12110 0 10101199 3-3/8' 4 12125- 12145 0 03J251f1T r 4 12140-12160 0 09/28/96 ¡4-1fl" LNR. 12.6#, 13-C,.o152 IIpf. D =3.968" 12283' I DA1ë RBI BY awMan'S DIto1ë ÆVBY ca.v..ens R\lDHOE 8Á Y UNT 111OM'1 ORIGINAL COMPLETION 06101102 RIAl Gl V lJP[)\"IE WB.L: B-02A 0&'1 W96 RIG SŒTRAO<: PElWfTNcx 1961110 0112Q'01 56-SL T CONVERTeD TO CAW AS API No; 50.029-20066-01 03109101 SIS-LG FJN,f. L 961' SNL & 1598' wa. See. 31. T11 N. R14E 07104f01 CtfKAK CORRB:TIONS BP Explorlltlon (A-hI JUt ~ 1 lUUL . . FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AlO) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~~CA!M~~Ef) í: \ l\~j \ \ \ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B-02A Sundry Number: 306-328 Dear Mr. Cismoski: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~day of September, 2006 Enc!. '... AJ .\ (\ \~ lJ f{\'i 0., I} ~ ~).z,?k rJ'75 ~/«/··" REC'EWÆfi)ZlI~t;, . STATE OF ALASKA _ /-6 ALASKA Oil AND GAS CONSERVATION COM~ON SEP 2 6 2006 APPLICATION FOR SUNDRY APPROVAL 0·, & G C Commission 20 AAC 25 280 Alaska I as ons. 1. Type of Request: o Abandon o Suspend 181 Operation Shutdown o Perforate o Time Extension o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. PermitTo Drill Number. BP Exploration (Alaska) Inc. ~ Development D Exploratory 196-111/306-276 / 3. Address: D Stratigraphic D Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20066-01-00 7. If peñorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU B-02A / Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028310 68.4' Prudhoe Bay Field / Prudhoe Bay Pool 12>. ....... ....... .... .... ...... J >. ..... > .....////./)//?.... . ./)... . .... Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12283 9075 725 / 725 725 None Casino Lenoth Size MD I TVD Burst CollaDse Structural 107' 30" 107' 107' Conductor 2308' 20" 2308' 2308' 1530 520 Suñace 2192' 16" 2192' 2192' Intermediate 4545' 13-318" 4545' 4323' Production 5663' 9-5/8" x 10-3/4" x 9-5/8" 5663' 5196' Liner 4920' 7" 5465' - 10385' 5042' - 8613' 7240 5410 Liner 2116' 4-1/2" 10167' -12283' 8458' - 9075' 8430 7500 Peñoration Depth MD (ft): I Peñoration Depth TVD (ft): I Tubing Size: / Tubing Grade: Tubing MD (ft): 10400' - 12160' I 8624' - 9034' 4-1/2", 12.6# L-80 636' & 1200' - 10171' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer I Packers and SSSV MD (ft): 10115' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Statu~er proposed work: W4A- Commencina Operations: September 22, 2006 Oil D Gas ~gged D Abandoned 17. Verbal Approval: Date: 9/22/2006 DWAG DGINJ DWINJ D WDSPL Commission Representative: Winton Aubert 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer David Reem, 564-5743 Prepared By Name/Number: Signature / " ~h O_;. .../"'..,. Phone 564-4303 Date 7h~/d Terrie Hubble, 564-4628 - ¿:/ Commission Use Only I I Sundry Number: .'J.ríD.. ~~ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: RBDMS 8Ft SEP 2 9 2006 Subsequent Form Required: ArpWJ \/td Crto..·- £J 4-0 ~ v'J ~¡".ed ~ v.a~t ~tiww.. "L 'MISSIONER APPROVED BY Date 9- t! ,-ðý Approved Bv: THE COMMISSION Form 10-403 Revised 06/2006 L/" \ V- I' \ Submit In Duplicate l/ . ORIGINAL . . B-02A Rig Workover - Temporary Suspension BP requests approval to temporary secure B-02A and move the rig off. The well status prior to the workover and highlights of this workover attempt are detailed below. Well Status (Pre-Workover) The well has corroded 4-%" L-BO tubing. The 9-5/8" x 4-1/2" annulus is cemented in from -830' - 1780' MD. The 4-1/2" tubing has been jet cut just above the top of cement (-799' MD). A 'Fasdrill' plug is set in the tubing tail (07/26/2005) but has failed by all indications. A 2nd 'Fasdrill' plug is set in the 4-1/2" tubing at 10124' MD (08/23/2006). Workover Scope: Doyon 16 moved over B-02 on September 4, 2006. After the tree was removed and BOPE were rigged up, the tubing was chemically cut at 10,048, tubing holes were shot at 1795', and the tubing was jet cut through the annular cement plug (see attached well bore diagram). Following a lubricate and bleed well control method, a kill string was stipped to bottom and the well was circulated dead. On September 15, the free tubing above a pre-rig jet cut at 799' was pulled to the floor. The annular cement was milled from 817' to 1224' and the 4-1/2" tubing was retrieved. Milling progress was slow~ than anticipated and some sections of 9-5/8" are suspected to have been retrieved. On Friday, September 19, the decision was made to secure the well and temporarily suspend operations. This decision was based on the unexpected slow pace of the milling and the probability of exiting the 9-5/8" casing with the BHA. A composite bridge plug was set at 800' an&of cement was placed on top of the plug. The well was turned over to 9.8 ppg brine, a 4-1/2" kill string was set to 636' and the tubing and IA were capped with 20 bbls of diesel for freeze protection. /' TREE= 7-1116" CAMERON WELLHEAD= MCEVOY ACTUA TOR= BAKER KB. ELEV = 68.68' BF. ELEV = 40.57' KOP = 2750' Max Angle = 82@ 10879' Datum MD = 10983' Datum TVD = 8800' SS B-02A Proposed 113-3/8" CSG, 68#, K55,ID= 12.415" H 4545' 19-518" x 10-314" X-OVer H 1968' I 110-3/4" CSG, 55.5#, K-55, .0925 bpf, ID = 9.76" H 2380' 7" LNR, 26#, L-80, .0383bpf, ID = 6.276" 19-5/8" X 7" BKR PKR / TIEBACK, 10 = 7.50" H 1 9-5/8" X 7" BKR LNR HGR, 10 = 6.18" I 19-5/8" CSG, 47#, ~O, 10 = 8.681" I 7" X 4-112" TlWTlEBACK PKRW/ SEAL ASSY 14-112" lBG, 12.6#, L80, .0152 bpf, 10 = 3.958" 17" X 4-112" TMI S-6 PKRlTEBACK, 10 = 3.850" H 10174' TlWDTH LINER HANGER, 10- 3.922" 10185' 17" LNR, 29#, 13-CR-80, .0371 bpf, ID = 6.184" H 10385' I ÆRFORA TION SLMtM RY REF LOG: AWS BHes 07/29/96 ANGLEATTOPÆRF: 48 @ 10400' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DAlE 2" 4 10400-10410 C 08/17/97 2" 4 11920 - 11940 0 10/01/99 3-3/8" 4 11960 - 11970 0 03125/97 3-3/8" 4 11970-11990 0 10/13/96 2-1/8" 4 12012 - 12032 0 09/29/96 1 .56" 4 12040 - 12050 S 08/01/96 2" 4 12090-12110 0 10/01199 3-3/8" 4 12125 - 12145 0 03/25/97 3-3/8" 4 12145 - 12165 0 10/13/96 2" 4 12140 - 12160 0 09/28/96 DAlE 11/09n7 08119/96 07/04/01 06107/02 03121/03 03128/03 REV BY COIIIMENTS ORIGINAL COMPLETION RIG SIDETRACK CHlKAK CORRECTIONS RLIIlh GL V UPDA TE JDIN/KK ÆRF CORRECTIONS JCM'TlH GL V UPDATE DAlE 08111/06 625' 636' 725' 800' 1200' 1415' 1720' /' 4-1/2" HES "XN" NIP, ID = 3.725" 4-112" 1 ~. -80 NSCT Workstring .O.C. ~ Plug HES 'Fasdrill' Bridge Plug /' Top, Cut 4-1/2" Tubing Jet Cut, 4-112" Tubing Jet Cut, 4-112" Tubing NOTE: WELL WAS LEFT W/9.8 NaCI BRINE IN ANNULUS AND 20BBLS DIESEL F/P. 10048' 10124' 10104' 10115' 10138' 10159' 10171' Chemical Cut, 4-112" Tubing HES 4-1/2" 'Fasdrill' Bridge Plug / 1-14-1/2" HES X NIP, 10 - 3.813" , -i7" X 4-112" BKR S-3 PKR, ID = 3.875" I 1-14-112" HES X NIP,ID-3.813" I 1-14-112" HES XN NIP,ID= 3.725" I -14-1/2" WLEG, ID = 3.958"1 4-112" AVA DIN REìR PATCH, 10- 2.441" TOTAL LENGTH = 35' 7" (08/17/97) 7TD H 12180' I 14-1/2" LNR, 12.6#, 13-C,.0152 bpf, 10= 3.958" H 12283' I REV BY WNIIS COMIIIENTS PROPOSED RWO PRUDHOE BA Y UNIT WELL: B-02A ÆRMIT No: '1961110 API No: 50-029-20066-01 SEC 31 , T11 N, R14E, 961' SNL & 1598' WEL BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 \ !:\Íé \\ \ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBD B-02A Sundry Number: 306-276 (. <.. Dear Mr. Cismoski: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisLt day of August, 2006 Encl. Il~ <61/6~~ [)Ç1::S Ó/ I ~/6 ,/VI, Qlo~ " STATE O~ ALASKA \.1"1' 0 ~ r\ß \ \ h \f ALA OIL AND GAS CONSERVATION COM ION ( rv, LJ \G\ V APPLICATION FOR SUNDRY APPROVAL --V 20 AAC 25 280 Alaska Oil & Gas Cons C REC~ÈDð" \ r I ~ ....1# AUG 1 5 2006 . OfT1mISSlon 1. Type of Request: o Abandon o Suspend ;{ 0 Operation Shutdown o Perforate o Time ExteAlåOrage o Alter Casing ~ Repair We I 0 Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program ~ Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 196-111 ,./ 3, Address: D Stratigraphic D Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20066-01-00 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: PBU B-02A /' Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field 1 Pool(s): ADL 028310 68.4' Prudhoe Bay Field 1 Prudhoe Bay Pool t~. ...... .> ,.:...,. .' .......i. .i» ·i... <><U.i..· i'" ......... .i .. T » ii.·.. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth M D (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12283 9075 10149 / 8444 10149 None Casino Lenath Size MD / TVD Burst . CollaDse Structural 107' 30" 107' 107' Conductor 2308' 20" 2308' 2308' 1530 520 Surface 2192' 16" 2192' 2192' Intermediate 4545' 13-3/8" 4545' 4323' Production 5663' 9-5/8" x 10-3/4" x 9-5/8" 5663' 5196' Liner 4920' 7" 5465' - 10385' 5042' - 8613' 7240 5410 Liner 2116' 4-112" 10167' - 12283' 8458' - 9075' 8430 7500 Perforation Depth MD (YI Perforation Depth TVD (ft): I Tubing Size: / Tubing Grade: Tubing MD (ft): 10400' - 12160' 8624' - 9034' 4-112". 12.6# L-80 10171' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer / I Packers and SSSV M D (ft): 10115' 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal D BOP Sketch D Detailed Operations Program /~' D Exploratory 181 Development o Service 15. Estimated Date for Septembt 1, )006 16. Well Status after proposed work: CommencinQ ODerations: 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Dat~J DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Prepared By Name/Number: Signature Î /lu ~'A Phone 564-4303 Date Terrie Hubble. 564-4628 ~ P' Commission Use Onlv I Sundry Number::!iXo - ~I (0 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: T -e ~ -t- ßOP[:: f-o 3Soo re....:· RBDMS BFL AUG 2 1 2006 Subsequent Form Required: 10- r~ A ~ APPROVED BY ßj¿~ Approved Bv: /I COMMJ.8SIONER THE COMMISSION Date Form 10-403 Revised 06/20~ R \ Gm J ~ -.......- o/ibmifln Duplicate . . Obp GL B-02A Rig Workover Current Status: An RWO was attempted in August 2005. The tubing is cemented in place from -830' to -1780' and a composite bridge plug was set in the tubing tail. The tubing was jet cut above the cement at -800'. After several attempts of circulating the well dead, the rig moved off. During subsequent circulation attempts in May 2006, the composite bridge plug appears to have failed. Current injectivity // into the formation is -5.0 bpm at 600 psi. Scope of Work: Pull 4-%" completion, run and cement to surface 7" tie-back liner, run 4-Y:z" 13CR-80 completion. MASP~. 2300)psi Well T pe:)'4oducer Estima'- Start Date: September 1, 2006 Pre-ri F 1 S 2 E 3 F 4 0 5 0 6 re work: Load & kill well w/ 9.8ppg brine. B/H well w/ 2X displacement (-825bbls) using two (2) pumps- one 1 on the IA and one 1 on the tubin . Drift thru tubin to - 10135' MD Run & set Com osite BP uickdril or fasdril at -10124'. CMIT - TxlA / 1000 si /" Check the tubing and IC casing hanger lock down screws. Completely back out and check each LOS for breaka e. PPPOT - T to 5000 si and PPPOT -IC to 80% of colla se ratin Set a BPV. Remove well house & flow line. Level pad as needed for the ri Proposed Procedure (9- 1. MIRU. NO tree. NU and test BOPE t ~ I', psi. Circulate out diesel freeze protection fluid and circulate well to clean 9.8 ppg brine. , 2. Pull and LD 4-Y:z" tubing string to the cu: 3. PU 6.75" 10 burn shoe and wash pipe to burn over 500' of 4-1/2" tubing. 4. PU 3-5/8" multi string cutter, cut 4-1/2" tubing above remaining cement. // 5. Fish 4-1/2" tubing 6. Repeat steps 3 thru 6 until we've recovered all cemented tubing. 7. RU EL and chemical cut the 4-1/2" tubing iêt 2nd full joint above the packer 8. PU 7" liner and sting into tieback receptacle t 5 65' I 2. 7 1::,1::,) {. WGA- 9. Cement 7" x 9-5/8" annulus to ~3e with of Class "G" cement w/ GasBlock. 10. Run 4-'JI:¡" 13CR-80 completion with Baker ' packer. Position packer at -9980' MD. 11. Displace the IA to packer fluid and set the packer. / 12. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 13. Set BPV. NO BOPE. NU and test tree. RDMO. , , TREE = 7-1/16" CAMERON SA NOTES: 4-112" CHROMELNR WELL SDTRK'D WELLHEAD= MCEVOY B-02A OFF WHIPSTOCK SET IN 9-5/8" CSG (NOT SHOWN). ACTUATOR= BAKER OLD WELLBORE BELOW 9- 5/8" M ILLOUT WINDOW KB. ELEV = 68.68' NOT ON DIAGRAM. WELL> 70 DEG@ 10725', BF, ELEV = 40,57' V ~ 1 KOP- 2750' 1968' -19-518" X 10-3/4" XO I Max Angle = 82 @ 10879' ¡... - 2192' -1 16" CIRCULATION STRING I Datum MD = 10983' IlliG CUT (07127/05) I 799' - Datum ND = 8800'SS . 2204' -14-1/2" HES HXO SSSV NIP, ID - 3.813" I ~ - L.. 2308' -120" CSG, 94/133#, H-40IK-5S I r I-' -1 10-3/4" X 9-5/8" XO I 110-314" CSG, 55.5#, K-55. .0925 bpf. ID = 9.76" I 2380' 2380' 113-3/8" CSG. 68#. KS5. ID = 12,415" I 4545' H ~ GAS LIFT MANDRELS Minimum ID = 2.441" @ 10386' ST MD TVD DE\! TYÆ VLV LATCH PORT DATE 4-1/2" AVA DWP RETR. PATCH 6 2977 2969 16 KBG-2-LS DOME !NT 20 03127/03 ~ 5 5449 5029 39 KBG-2-LS SO INT 16 03/27103 4 7466 6432 42 KBG-2-LS DMY INT 0 ~ 3 8776 7378 43 KBG-2-LS DMY !NT 0 19-5/8" X 7" BKR PKR / TIEBACK, ID = 7,50" H I 2 9510 7915 43 KBG-2-LS DMY !NT 0 5465' ~ ~ 1 10078 8323 43 KBG-2-LS DMY INT 0 I 9-5/8" X T' BKR LNR HGR. ID = 6.18" I 5479' I 9-5/8" MILLOUT WINDOW I 9-5/8" CSG. 47#, N-80. ID = 8.681" I 5663' I-- 5663' - 5703' ( OFF WHIPSTOCK ) I I 10104' -14-1/2" HES X NIP. ID = 3.813" I :8 ~ 10115' H 7" X 4-1/2" BKR S-3 PKR, ID - 3.875" I L::-d 10138' -14-1/2" HES X NIP. ID = 3.813" I M I 10149' H4-1/2"FASDRlLL A..UG (SET 7/26/05) I - ----r -14-1/2" HES XN NIP, ID = 3,725" I 10159' I T' x 4-1/2" TIW TIEBACK PKR WI SEAL ASSY I 10167' I I 14-112" TBG. 12,6#. L80, ,0152 bpf. ID = 3.958" I 10169' ~~ ~ 10171' /-14-112" WLEG, ID - 3,958" I IT' X 4-1/2" TIW S-6 PKRlTIEBACK. ID = 3.850" H 10174' --~ ~ I TIW DTH LINER HANGER. ID - 3,922" I 10185' I P" IT' LNR, 29#, 13-CR-80. ,0371bpf.ID=6,184" I 10385' I .. .. I 10386' 4-112" AVA DW RETR. PATCH.ID = 2.441" I ÆRFORA TION SUMMARY TOTAL LENGTH = 35' 7" (08117197) REF LOG: AWS BHCS 07/29/96 ANGLEATTOPÆRF: 48@ 10400' ;' 12180' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10400 - 10410 C 08/17/97 2" 4 11920 - 11940 0 10/01199 3-3/8" 4 11960 - 11970 0 03/25/97 3-3/8" 4 11970 - 11990 0 10/13/96 2-1/8" 4 12012 - 12032 0 09/29196 1,56" 4 12040 - 12050 S 08101/96 2" 4 12090-12110 0 10/01/99 3-318" 4 12125 - 12145 0 03/25/97 I 4-112" LNR, 12.6#. 13-C, .0152 bpf. ID = 3,958" H 12283' I 3-3/8" 4 12145 - 12165 0 10/13/96 2" 4 12140 - 12160 0 09/28/96 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 11/09177 ORIGINAL COMPLETION 07/26/05 RWLiPJC FASDRILL PLUG WELL: B-02A 08/19/96 RIG SIDETRACK 08/02105 GJBITLH CUT lliG PERMIT No: 1961110 07104101 CHlKAK CORRECTIONS API No: 50-029-20066-01 06107102 RLiTLH GL V C/O SEC 31. T11N, R14E, 961' SNL & 1598' WEL 03/21/03 JDW/KK PERF CORRECTIONS 03/28103 JCMlTLH GLV C/O BP Exploration (Alaska) TREE= 7-1116" CAMERON WELLHEAD= MCEVOY ACTUA TOR= BAKER KB. B...EV = 68.68' BF. B...EV = 40.57' KOP = 2750' Max Angle = 82 @ 10879' Datum MO = 10983' Datum TVO = 8800' SS 1 9-5/8" x 10-3/4" X-Over 110-3/4" CSG, 55.5#, K-55, .0925 bpf. 10 = 9.76" I 113-3/8" CSG. 68#, K55.1D= 12.415" I B-02A Proposed Minimum ID = 2.441" @ 10386' 4-1/2" AVA DWP RETR. PATCH 17" LNR. 26#, L-BO, .0383bpf, 10 = 6.276" I I 9-5/8" X 7" BKR PKR / TIEBACK, 10 = 7.50" -i 5465' 19-5/8" X 7" BKR LNR HGR, 10 = 6.18" I 5479' 19-5/8" CSG, 47#, N-80. 10 = 8.681" 14-1/2" TBG. 12.6#, 13Cr-80, 10 = 3.958" 1- 17" X 4-1/2" Unique Machine Overshot I 17" X 4-1/2" TIVVTIEBACK PKR W/ SEAL ASSY 14-1/2" TBG. 12.6#, L80. .0152 bpf, 10 = 3.958" 17" X 4-112" TIVV S-6 PKRITIEBACK, 10 = 3.850" I TIVV OTH LNER HANGER, 10 = 3.922" I 17" LNR, 29#. 13-CR-BO, .0371bpf, 10= 6.184" I 10385' ÆRFORA TION SUMJIARY REF LOG: AWS BHeS 07/29/96 ANGLEATTOPÆRF: 48 @ 10400' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10400 - 10410 C 08/17/97 2" 4 11920 -11940 0 10/01199 3-3/8" 4 11960 - 11970 0 03/25/97 3-3/8" 4 11970 - 11990 0 10/13/96 2-1/8" 4 12012 - 12032 0 09/29/96 1.56" 4 12040 - 12050 S 08/01/96 2" 4 12090 -12110 0 10/01/99 3-3/8" 4 12125 - 12145 0 03/25/97 3-3/8" 4 12145 - 12165 0 10/13/96 2" 4 12140 - 12160 0 09/28/96 DATE 11109/77 08/19/96 07/04/01 06/07/02 03/21/03 03/28/03 REV BY COtv'MENTS ORIGINAL COMPLElDN RIG SIDETRACK CHlKAK CORRECTIONS Rutlh GL V UPDATE JDW/KK ÆRF CORRECTIONS JCMITlH GLV UPDATE DATE REV BY COMvtENTS -500' 2192' -2200' 2308' -1TOPOFCBvENT 1 / -116" CIRCULATION STRING 1 -14-112" HES "X" NP, 10= 3.813" -120" CSG, 94/133#, H-401K-55 I GAS LIFT MANDRaS ST MO TYÆ VLV 6 2977 4.5" x 1" DC!< 5 5449 4.5" x 1" DMY 4 7466 4.5" x 1" DMY 3 8776 4.5" x 1" DMY 2 9510 4.5" x 1" DMY 1 10078 4.5" x 1" DMY -i4-1/2" HES X NP, 10 = 3.813" 1 7" X 4-112" BKR S-3 PKR. 10 = 3.875" 4-1/2" HES X NP, 10 = 3.813" 101M' H4-1I2" HES X NIP, 10 = 3.813" I 10115' -17"X4-1I2"BKRS-3PKR,10=3.875" I 10138' H4-1/2" HES X NIP, 10 = 3.813" I 10159' H4-1/2" HES XN NIP, 10 = 3.725" I 10171' -14-112" WLEG, 10 = 3.958" I 4-1/2" AVA DW RETR. PATCH, 10= 2.441" TOTAL LENGTH = 35' 7" (08/17197) ì 12180' I 14-1/2" LNR, 12.6#, 13-C..0152 bpf, ID= 3.958" H 12283' I PRUDHOE BA Y UNrr WELL: B-02A PERMrrNo: 1961110 API No: 50-029-20066-01 SEC 31. T11N, R14E, 961' SNL & 1598' WEL BP Exploration (Alaska) B-02A Revised Well Plan . l~~..H~ . Subject: B-02A Revised Well Plan From: "Cismoski, Doug A" <CismosDA@BP.com> Date: Fri, 18 Aug 2006 10:26:33 -0800 To: winton_aubert@admin.sta s CC: "Reem, DavidG" <Reem Winton- The workover team met and decided upon, based on our operations and well integrity policy that in the case of B-02A. the cement top between the new 7" and 9-5/8 annulus will be brought to surface. I've listed the revised the procedure below including a revised cement volume as well as an updated proposed well diagram. I'm out on vacation for the next two weeks. Please contact Dave Reem at 564-5743 during my absence. Doug (", ~~" £- 'iI"J"'-~ ";;: Ü \:>......~~, \-' ,,!,¡¡¡io F, ~;~, ¿ New Proposed Procedure 1. MIRU, ND tree. NU and test BOPE to 3500 psi. Circulate out diesel freeze protection fluid and circulate well to clean 9.8 ppg brine. 2. Pull and LD 4-%" tubing string to the cut. 3. PU 6,75" ID burn shoe and wash pipe to burn over 500' of 4-1/2" tubing, 4. PU 3-5/8" multi string cutter, cut 4-1/2" tubing above remaining cement. 5. Fish 4-112" tubing 6. Repeat steps 3 thru 6 until we've recovered all cemented tubing. 7. RU EL and chemical cut the 4-1/2" tubing in the 2nd full joint above the packer 8. PU 7" liner and sting into tieback receptacle at 5465' 9. Cement 7" x 9-518" annulus to surface with 148 bb!s of Class "G" cement wI GasBlock, 10. Run 4-%" 13CR-80 completion with Baker S-3 packer, Position packer at -9980' MD, 11. Displace the IA to packer fluid and set the packer. 12. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD, 13. Set BPV, ND BOPE, NU and test tree. RDMO. «B-02A Proposed,pdf» ! I ---------=¡r~~~;~~;-Desc~"i-~ti~~~~--()-2AProposed.Pdf- ---~ !!B-02A proposed.Pd~! Content-Type: application/octet-stream!1 Ii tcontent-Encodin~ase64______m! - - -- --------------_._~------_..- 1 of 1 8/18/2006 11 :08 AM TREE= 7-1/16" CAMERON WELLHEAD= MCEVOY ACTUA TOR= BAKER KB, ELEV = 68.68' BF, ELEV = 40.57' KOP = 2750' Max Angle = 82 @ 10879' Datum MD = 10983' Datum TVD = 8800' SS 9-5/8" x 10-3/4" X-Over 110-3/4" CSG. 55.5#, K-55. .0925 bpf. ID = 9,76" 113-3/8" CSG. 68#, K55, ID= 12.415" B-02A Proposed Minimum ID =2.441" @ 10386' 4-1/2" AVA DWP RETR. PATCH IT' LNR. 26#, L-80. ,0383bpf, ID = 6,276" I I 9-5/8" X 7" BKR PKR / TIEBACK. ID = 7,50" H 5465' 9-5/8" X T' BKR LNR HGR. ID = 6,18" 1 5479' 19-518" CSG, 47#, N-80, ID = 8,681" 1 4-1/2"TBG. 12,6#. 13Cr-80.ID=3.958" I- I T' X 4-1/2" Unique Machine Overshot I 17" X 4-1/2" TrN TIEBACK PKR W/ SEAL ASSY 1-1 14-1/2" TBG, 12,6#. L80. ,0152 bpf, ID = 3,958" 1-1 10167' 10169' ÆRFORA TION SUMMARY REF LOG: AWS BHCS 07/29196 ANGLE AT TOP ÆRF: 48 @ 10400' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 10400 - 10410 C 08/17/97 2" 4 11920 - 11940 0 10/01/99 3-3/8" 4 11960 - 11970 0 03/25/97 3-3/8" 4 11970 - 11990 0 10/13/96 2-1/8" 4 12012 - 12032 0 09/29/96 1,56" 4 12040 - 12050 S 08/01/96 2" 4 12090 - 12110 0 10/01/99 3-3/8" 4 12125 - 12145 0 03/25/97 3-3/8" 4 12145 - 12165 0 10/13/96 2" 4 12140 - 12160 0 09/28/96 DATE 11/09/77 08/1 9/96 07/04/01 06/07/02 03/21/03 03/28/03 REV BY CH/KAK RL/tlh JDW/KK JCM/TLH COMMENTS ORIGINAL COMPLETION RIG SIDETRACK CORRECTIONS GLV UPDATE ÆRF CORRECTIONS GL V UPDATE DATE REV BY COMMENTS -i 16" CIRCULATION STRING I -14-1/2" HES "X" NIP. ID = 3.813" -f 20" CSG, 94/133#. H-40/K-55 I GAS LIFT MANDRELS ST MD TYÆ VLV 6 2977 4,5" x 1" DCK 5 5449 4,5" x 1" DMY 4 7466 4.5" x 1" DMY 3 8776 4,5" x 1" DMY 2 9510 4,5" x 1" DMY 1 10078 4,5" x 1" DMY 10104' 10115' 10138' 10159' 10171' 1-14-1/2" HES X NIP, ID - 3,813" 1 7" X 4-1/2" BKR S-3 PKR, ID = 3,875" 4-1/2" HES X NIP, ID = 3,813" H4-1/2"HESXNIP.ID=3,813" 1 -f 7" X 4-1/2" BKR S-3 PKR. ID = 3,875" I 1-14-112" HES X NIP, ID= 3,813" I 1-14-1/2" HES XN NIP. ID = 3,725" I -14-1/2" WLEG, ID = 3.958" I 4-1/2" AVA DW RErR. PATCH, ID - 2.441" TOTAL LENGTH = 35' 7" (08/17/97) / 12180' I 14-1/2" LNR. 12,6#, 13-C.,0152 bpf, ID= 3,958" 1-1 12283' 1 PRUDHOE BA Y UNrr WELL: B-02A ÆRMrr No: 1961110 API No: 50-029-20066-01 SEC 31, T11 N, R14E, 961' SNL & 1598' WEL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATIN: Beth Well Job# Log Description Date 8L 02-308 10980587 RST 07/17/05 1 PSI-07 10674389 RST 10/27/03 1 PSI-07 10679045 RST 12/26/03 1 L3-02 11072860 RST 06/13/05 1 X-16A 10980531 RST 03/01/05 1 F-30 10987523 RST 06/22/05 1 W-31 10913021 RST 06/30/05 1 Z-15 10980580 RST 07/10/05 1 C-30 10980583 RST 07/13/05 1 W-39A 10928650 MCNL 10/16/05 1 18-31A 10942210 MCNL 04/28/05 1 H-02A 10928622 MCNL 04/05/05 1 05-24A 10928609 MCNL *(PRINT SENT 1/24/05) * 12/22/04 K-06A 11075903 MCNL 07/30/05 1 L-03 10913041 OH LDWG EDIT FOR WIRELlNE DATA 08/01/05 2 B-02A /9ú-l(f 10889169 SCMT 09/22/04 H-05 10674407 C8L 01/21/04 G-13A 10563175 SCMT 06/17/03 E-06A 11051045 SCMT 05/19/05 W-20 10672389 USIT 06/03/04 MPF-87A 10708043 US IT 01/08/04 MPA-03 11058243 USIT 09/07/05 MPF-89 11051088 US IT 08/17/05 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SÇANNED NOV 2 9 2005 Date Delivered: \. 'c....: - \'ì'\ \ -f If V\ \ j(fj';; ,} . ,_ _l\ ~ diu 11/17/05 NO. 3602 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 / I" I-,_~ Field: Prudhoe Bay, Milne Pt. r qW/ Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 --- 1 1 1 1 1 1 1 1 1 -~/' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth., r- I~ Rece;ved by: /!;'l CI!L I -dJ.; l Œ B-O~A (PTD # 1961110) Classifièd as Problem Wèll ~ 7(z..~ldt Subject: B-02A (PTD #1961110) Classified as Problem Well ~ef'l From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Tue, 20 Jul 2004 07:38:23 -0800 To: "Holloway, Emberley L" <Emberley.Holloway@BP.com>, "GPB, Fld TL" <GPBFldTL@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, Well Pads BAX" <GPBWeIIPadsBAX@BP.com> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWeIlIntegrityEngineer@BP.com>, "Reeves, Donald F" <ReevesDf@BP.com> All, Well B-02A (PTD #1961110) has been found to have sustained casing pressure on the OA. The TIOls on 07/18/04 were 2380/420/1600/610/610. Wellhead pressure was bled off the annuli and increased 1300 psi on the OA overnight. The plan forward for this well is as follows: 1. WIE: Eval well for secure and diagnostic testing. {'['o 4q -¿ L~.~th ( Lt- ~~è þlic.( f The well has been classified as a Problem well. Please call if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659- 5102 Pager: (907) 659-5100 x1154 '~J" Z>V°r~ ~ ,. 4 lLer;. I c.. ~~ =- Jbt.:II.."f'>' ?J(J¡Zf'" 155 3~ ¡ OA- fTe~Sl,~~ > 494, ,A.A~lP l. R ec(:~.~+- Pru:lt\.( ~_f, \ \BBL) ç\J\.c ç ) ( ï3öL ) 0Q~ 0.\ (~(~ l,\J, eRr .3~'cA 7' 3u' Yl Z- 1Q4 IS, (t¡ti '¿.- L: ' 'CJ , .\\,Cj ; 04 26 't4 \ ~,'67 4-'ó '014 I r\~l '04 ZA,<O<t\~ 4Y(:'1 b (¡ 3 '~3lf) .l'4tl ~\ 'D4- lSBOS 510 3'~3 lC1 'iJ'7':' , I Ù ~ w~Qi s.eCL\r4~ ~ C-Itv-\L 0 I~^ (ßp L'ul U ~"~l_r>ftl Gr"~f) Jí<-tc¡ 1b~~ I of I 7/28/200..J 9:29 AI'vl .~ ~ SAFETY NOTES: 4-1/2" a-tROM:: Lr-.R. Wa.L 5DlRK'D OFFWHPSTOQ< SET IN 9-518" CSG (NOT SHOWN). OlD WaLBORE BaOW 9- 518" ~LLOUT WINDOW NOT ON DIAGRAM. W8.L> 70 DEG @ 10725'. TREE= 7-1/16" CAMERON WELLHEAD= ~EVOY Acrua..TOR= BAKER KB. ELEV = 68.68' BF. ELEV = 40.57 KOP = 275(1 Max Angle = 82 @ 10879' 'Datum MD = 10983' Datum TVD = 8800' 55 B-02A J ~ , . - 9-&8" X '0-314" XO I - '16" CR::LLA 110N 5TRIf\G 1 - 4-1/2" HES HXO SSSV NP. D = 3.813" 1 H2O" coo, 94/133#, H-401K-55 H10-3/4" X 9-518" XO I 1968' 2192' 2204" 2308' 2380" - ~. ~ ~ .;.'z.c ~tJ 1.')'IJ.) O~ \tP~ ~ I .. 110-3/4" CSG, 55.5#, K-SS, .0925 bpf, ID = 9.76" H 2380" 113-~8'~ 68ft, 1<55\ ~tI 4545" ~ ~~W'-1P~''7'53 (J"JI ') Minbnum ID = 2.441" @-to3sý 4-1/2" AVA DWP RETR. PATCs.t:l ~ Gc\5 LIFT MAN~as lYD œv TYÆ VLV LATCH FORT DATE 2969 16 KBG-2-LS!:MY BTM 00/07/02 5029 39 KBG-2-LS Q\1Y BTM 00/07/02 6432 42 KBG-2-LS BTM 7378 43 KBG-2.LS BTM 7915 43 KBG-2-LS BTM 8323 43 KBG-2-LS BTM ST M) 6 2977 5 5449 4 7466 3 8776 2 9510 1 10078 -1 19-518" X 7" BKR A<R / TlæACK~ ID = 7.50"H 5465" I 19-518" X 7" BKR LNR HGR, ID = 6.1 B" H. 5479' 1 , ~ ~ 9-518" MLLOur WINOOW 5663' - 5703' ( OFF WHIPSTOCK) I 9-5/S" CSG, 47#, NoSO, ID = 8.681" H 5663' I--- H4-1I2" HES X NIP, ID= 3.813" H7" X 4-1/2" BKRS-3PKR, ID= 3.S75" I H4-1/2" HES X NIP, ID= 3.813" H4-1/2" HES XN NP, D = 3.725" I I 10104' I 10115" I 1 0138" r 10159" II I Z ~ ~ ~ 7" X 4-1/2" TIW llEBACK PKR W/ SEAL ASSY - 10167' 4-112" lBG. 12.6#, LBO, .0152 bpf, D =3.958" - 10169" i '~ I 10171" H4-1/2"WLEG, ID= 3.958" I J ¥ ... l ~ A 17" X 4-1/2" TM/ 5-6 A<PJTlffiACK, ID = 3.850" "i 10174' I I TIW DTH LINER Hð.NGER, ID= 3.922" 1- 10185" 1 17" LNR. 29#,13-CR-SO, .0371bpf, ID= 6.184" H 10385' I Hð.-1/2" A V A DJII' RETR. PA TCH. ID = 2.441" I TOTAL LENGTH = 35'''' (06/17/97) PERFORATION SUMMt\ RY RB= LOG: AWS BI-CS 07/29/96 ANGLEA T TOP PERF: 46 @ 1040(1 !\bte: Refer to R"oduction DB for historical perf da1a SIZE SFF INlERVAL Opn/Sqz DATE 2" 4 10400 - 10410 C 08/17/97 2:' 4 11920- 11940 0 10/01199 3-3/8" 4 11960 - 11970 0 03/25/'ð'l 2-118" 4 12012- 12032 0 09/29/96 1.56" 4 12040 - 12050 5 08/01/96 2" 4 12090 - 12110 0 10/01/99 3-318" 4 12125- 12145 0 03/25/97 2" 4 12140 - 12160 0 09/28/96 14-1t2"LNR,12.6#,13-C,.0152bpf,D=3.958" H 12283' I DAlE 11/09177 08119/96 01/29/01 03JOBJ01 07/04101 RBI BY COWM8"JTS ORIGINAL COMPLETION RIG SIDElRAO< 5B-SL T CONVERlED TO CA rw AS SIS-lG FINAL CH'KAK CORREC1l0NS ~1E REV BY COMfvENTS 06107/02 RLlUh GL V UPQÞ. TE FRlDHOE BAY Ur-.IT W8...L: B-Q2A PERMrr No: 1961110 API No: 50-029-20066-01 961' SNL & 1598' WEL. Sec. 31, T11 N. R14E BP exploration (Alaska) ~ÇANNFD JUl 3 1 20'01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ CEMENT SQZ OF COCA & OOA Pa, tubing_ Stimulate _ Plugging _ Perforate _ Alter casing _ Repair well _X Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development ._X Explorato~._ Stratigraphic__ Servicem 4. Location of well at surface 961' FNL, 1598' FEL, Sec. 31, T11N, R14E, UM At top of productive interval 1281' FNL, 3176' FEL, Sec. 32, T11N, R14E, UM At effective depth 1764' FNL, 461' FEL, Sec. 32, T11N, R14E, UM At total depth 1790' FNL, 368' FEL, Sec. 32, T11N, R14E, UM (asp's 664041, 5949689)~ (asp's 668822, 5949475) (asp's 670477, 5949029) (asp's 670570, 5949005) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 107' Surface 2280' Intermediate 2164' Intermediate 4517' Intermediate 1940' Intermediate 412' Intermediate 3283' Liner 4920' Side Track Liner 2109' 6. Datum elevation (DF or KB feet) RKB 69 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-02A 9. Permit number / approval number ~ 196-111 10. APl number 50-029-20066-01 11. Field / Pool Prudhoe Bay Oil_Po.el.-.. -, t;',,. L 12283 feet Plugs (measured) 9075 feet !Vl- R 12180 feet Junk (measured) 9039 feet Size Cemented Measured Depth ;' 1;ruei:V-ertical Depth 30" 150 sx Permafrost 135' 135' 20" 5100 sx Permafrost 2308' 2308' 16" Circulating String, not 2192' 2192' cemented 13-3/8" 1200 sx Class 'G' 4545' 4323' 9-5/8" 3530 sx Class 'G' 1968' 1968' 10-3/4" same as above 1968' - 2380' 1968' - 2380' 9-5/8" same as above 2380' - 5663' 2380' - 5196' 7" 225 sx Class 'G' 5465' - 10385' 5042' - 8613' 4-1/2" 66 sx Class 'G', 168 sx 10174' - 12283' 8463' - 9075' Class 'G' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 11920'-11940', 11960'-11970', 12012'-12032', 12090'-12110', 12125'-12160' Perfs Behind Patch 10400'-10410'. Sqzd Perfs 12040'-12050' Open Perfs 8992'-8995', 8999'-9000', 9008'-9011', 9020'-9024', 9027'-9034' Perfs Behind Patch 8623'-8630'. Sqzd Perfs 9012'-9014'. 4-1/2", 12.6#, L-80 TBG to 10171'. 9-5/8" x 7" BKR Packer/Tieback @ 5465'; 7" x 4-1/2" BKR S-3 Packer @ 10115'. 7"x4-1/2" TIW PKR/Tieback w/Seal Assy @ 10167'. 7"x4-1/2" TIW S-6 PKR/Tieback @ 10174'. 4-1/2" HES HXO SSSV Nipple @ 2204'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well. operation Subsequent to operation OiI-Bbl Shut-In Shut-In Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas M l~~~orrect to the best of my knowledge. Title: Technical Assistant DeWayne R. Schnorr Suspended M Service March 19, 2003 Form 10-404 Rev 06/15/88 · ,,.,S.FDRiGiNAi Prepared by DeWayne R. Schnorr 564-51~M SUBMIT IN DUPLICATE B-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/17/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL 01/25/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-MITOA 03/08/2003 ANN-COMM (AC-EVAL AND REPAIR): FLUID SWAP 03/17/2003 CEMENT SQUEEZE: CEMENT SQUEEZE 03/17/2003 CEMENT SQUEEZE: CEMENT SQUEEZE 03/18/2003 CEMENT SQUEEZE: AC-MONITOR EVENT SUMMARY 01/17/03 T/I/O/O/O. SI/10/1.0/10/10. IA FL @ SURFACE. OA FL N.S. OOA FL N.S. (PRE LLRT OA x OOA). 01/25/03 T/I/O/O/O = SI/45/20/55/55. MIT - OA FAILED. LLR = 0.1 GPM @ 1050 PSI. (PRE CEMENT CIRC). OA FL N.S. PRESSURED OA TO 1000 PSI WITH 1.5 BBLS OF DIESEL. OAP DROPPED TO 720 PSI IN < 1 MINUTE AND CONTINUED TO DROP. REPRESSURED OA TO 1000 PSI WITH THE SAME RESULTS. NO CHANGES IN lAP, OOAP OR OOOAP. STARTED LLR TEST. LLRT. PUMPED 6.3 GALS OF DIESEL IN ONE HOUR AND ESTABLISHED A LLR OF 0.1 GPM AT 1050 PSI. DURING LLRT lAP INCREASED FROM 45 TO 70 PSI. DURING THE LAST 15 MINUTES OF THE LLRT THE lAP DROPPED TO 60 PSI. AFTER BLEEDING THE OAP TO 0 PSI, THE IA DROPPED BACK TO 55 PSI. FINAL WHP's = SI/55/0/55/55. 03/08/03 PUMPED 250 BBLS OF HOT CRUDE DOWN OOOA AND TAKE RETURNS UP THE IA TO A TIGER TANK. CHASED HOT CRUDE WITH 200 BBLS OF COOL CRUDE, RETURNED CRUDE TEMPS AVERAGED 43 DEGREES F, WITH NO WARM CRUDE SEGMENTS. 03/17/03 MIRU LRS (RIELESS) TO THE IA & DOWELL CEMENTERS (JOST) TO THE OOOA. CIRCULATE IN 150 BBLS 15.7 PPG ARCTIC SET 1 CEMENT DOWN THE OOOA TAKING RETURNS UP THE IA. ALLOWED CEMENT TO U-TUBE FROM THE OOOA INTO THE OOA WHILE INJECTING CRUDE, AT MINIMAL RATE, DOWN THE IA. OBSERVED CEMENT GELLING UP. IA PRESSURED TO 500 PSI, SHUT DOWN IA INJECTION. LEFT WELL SHUT-IN. 03/17/03 PUMPED 46 BBLS CRUDE DOWN IA TAKING RETURNS UP OOA TO TIGER TO TANK TO ASSIST WITH CEMENT SQUEEZE. <<< IA PRESSURED UP TO 500 PSI AS CEMENT SET UP DOWN HOLE >>> RDMO. 03/18/03 T/I/O/O/O = SINAC/IOIOIO. MONITOR WHP's. (POST OA CEMENT SQUEEZE). FLUIDS PUMPED BBLS 10 METHANOL 546 CRUDE 10 FRESH WATER 150 15.7 PPG ARCTIC SET I CEMENT. 716 TOTAL Page I 11-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/14/2003 PATCH TUBING / LINER: AC-EVAL; AC-FLUID LEVEL 03/15/2003 PATCH TUBING / LINER: PATCH TUBING ! CASING 03/15/2003 PATCH TUBING / LINER: MIT-IA; PATCH TUBING ! CASING 03/16/2003 PATCH TUBING / LINER: AC-MONITOR EVENT SUMMARY 03/14/03 TIO= 160/350/600 TBG & IA FLs for TBG Patch. TBG FL @ surface; IA FL @ 640'. 03/15/O3 4.5" CHROME ECLIPSE PATCH SET OVER GLM #4 TO STOP LEAK @ 7775.5'. PATCH WAS 37' IN LENGTH, MIN ID 2.255", MAX O.D. WAS 3.74" BEFORE SETTING. TIED INTO SWS LDL 12-21-02. TOP OF PATCH AT 7753', BOTTOM PACKER @ 7791' AND TOP PACKER @ 7756'. RDMO. LRS MIT-IA TO 3000 PSI PASSED. WELL RETURNED TO DSO TO POP. 03/15/O3 T/I/O=100/300/560 MIT IA to 3000 psi ---PASSED---/PUMP TO ASSIST E-LINE SETTING PATCH. 03/16/03 T/I/O = 130/470/590. MONITOR WHP's. (POST MITIA, TBG PATCH). Fluids Pumped BBLS 25 60/40 METHANOL WATER 25 TOTAL Page I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ CEMENT SQZ OF OOA & CA Pa, tubing_ Alter casing_ Repair well _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 69 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Ba~/Unit 4. Location of well at surface 8. Well number 961' FNL, 1598' FEL, Sec. 31, T11N, R14E, UM (asp's 664041, 5949689) B-02A ,, At top of productive interval 9. Permit number / approval number 1281' FNL, 3176' FEL, Sec. 32, T11 N, R14E, UM (asp's 668822, 5949475) 196-111 At effective depth 10. APl number 1764' FNL, 461' FEL, Sec. 32, T11 N, R14E, UM (asp's 670477, 5949029) 50-029-20066-01 At total depth 11. Field / Pool 1790' FNL, 368' FEL, Sec. 32, T11 N, R14E, UM (asp's 670570, 5949005) Prudhoe Ba)/Oil Pool 12. Present well condition summary Total depth: measured 12283 feet Plugs (measured) true vertical 9075 feet Effective depth: measured 12180 feet Junk (measured) true vertical 9039 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 107' 30" 150 sx Permafrost 135' 135' Surface 2280' 20" 5100 sx Permafrost 2308' 2308' Intermediate 2164' 16" Circulating String, not 2192' 2192' cemented Intermediate 4517' 13-3/8" 1200 sx Class 'G' 4545' 4323' Intermediate 1940' 9-5/8" 3530 sx Class 'G' 1968' 1968' Intermediate 412' 10-3/4" same as above . 1968' - 2380' 1968' - 2380' Intermediate 3283' 9-5/8" same as above 2380'- 5663' 2380' - 5196' Liner 4920' 7" 225 sx Class 'G' 5465' - 10385' 5042' - 8613' 66 sx Class 'G', 168 sx Side Track Liner 2109' 4-1/2" 10174' - 12283' 8463' - 9075' Class 'G' Perforation depth: measured Open Perfs 11920'-11940', 11960'-11970', 12012'-12032', 12090'-12110', 12125'-12160' Perfs Behind Patch 10400'-10410'. Sqzd Perfs 12040'-12050' true vertical Open Perfs 8992'-8995', 8999'-9000', 9008'-9011', 9020'-9024', 9027'-9034' Perfs Behind Patch 8623'-8630'. Sqzd Perfs 9012'-9014'. Tubing (size, grade, and measured depth) 4-1/2% 12.6#, L-80 TBG to 10171'. Packers & SSSV (type & measured depth) 9-5/8" x 7" BKR Packer/Tieback @ 5465'; 7"x 4-1/2" BKR S-3 Pl.~cl~r/j~ 1,1,0~ ~,5~. [~ ~ 7"x4-1/2" TIW PER/Tieback w/Seal Assy @ 10167'. 7"x4-1/2" TI~ ~k.,Pl~l'~li~o~kl.~ 10174'. 4-1/2" HES HXO SSSV Nipple @ 2204'. 13. Stimulation or cement squeeze summary jul ~ .~ ~002~ Intervals treated (measured) (see attached) '-' Treatment description including volumes used and final pressure I~l~e~,~l r~il ~ G~ (~;01~. t.~t;ttitH~i55tt-;: 14. Representative Daily Averaqe Production or Iniecfi~'~'bata ~nchrjr~,0~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation Shut-In 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -~~,~~'~LJ~.~,~~.~ Title: TechnicalAssistant sCANNED z. uu . Date,JuN 1,6,,,3002 ~ DeWayneR. Schnorr J~ ~ ! /"%1 ~, ! ~ . ~parecrb~-r~e. ayner~.Schnorr564-5174 ORiGiNAL SUBMIT IN DUPLICATE Form 10-404 Rev 06/15~88 · B-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/06/2002 ANN-COMM (AC-EVAL AND REPAIR): GAS LIFT--TO DUMMY VALVES 06/07/2002 ANN-COMM (AC-EVAL AND REPAIR): GAS LIFT--TO DUMMY VALVES 06/08/2002 ANN-COMM (AC-EVAL AND REPAIR): AC-MITT 07/08/2002 ANN-COMM (AC-EVAL AND REPAIR): AC-BLEED; AC-EVAL 07/10/2002 ANN-COMM (AC-EVAL AND REPAIR): AC-LOAD; CEMENT SQUEEZE EVENT SUMMARY 06/06/02 SET 4-1/2" SLIP STOP CATCHER SUB @ 5552' SLM. PULLED VALVES FROM STATIONS 5 & 6. JOB IN PROGRESS. 06/07/O2 SET 1" DV'S @ STATIONS 5 & 6. PULL 4-1/2" SLIP STOP CATCHER SUB @ 5552' SLM. SECURED WELL. <<< NOTIFIED DSO OF WELL STATUS >>> <<< DHD TO PERFORM MIT-T >>> 06/08/02 MIT - TEST TO 3500 PSI PASSED. (PRE OA CEMENT PROCEDURE). 0W0~02 MIT-T TO 3500 PSI --- PASSED. PREP OA FOR CEMENT JOB. T/I/O = SI/160/120/0/140 PREP OA FOR CEMENT JOB. INITIAL OA FL NEAR SURFACE. INITIAL IA FL @ SURFACE. BLED OAP FROM 120 PSI TO 80 PSI IN 40 MINUTES, MOSTLY FLUID RETURNS. SI, BLED, MONITOR FOR ONE HOUR. lAP HAS DROPPED FROM 160 PSI TO 100 PSI, NO CHANGE IN OOA OR OOOA PRESSURES AT THIS TIME. AFTER MONITOR OAP CAME UP 5 PSI TO 85 PSI AND lAP STAYED AT 100 PSI & NO CHANGES ON OOA OR OOOA PRESSURES AT ANYTIME. FINAL WHP's = SI/100/85/0/140 --- NO CHANGE IN OOA OR OOA PRESSURES. 07/10/O2 CEMENTED OOA AND oa (10 3/4" x 13 3/8" & 13 3/8" x 16") WITH 220 BBLS 11 PPG ARCTIC CRETE. FLUIDS PUMPED BBLS I PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (1 TEST) 322 CRUDE 4 DIESEL 253 FRESH WATER 220 11 PPG ARCTIC CRETE CEMENT 900 TOTAL Page 1 sCANNED ,Itll 3 IL ?005 SAFETY NOTES: 4-1/2" CHROIVE LNR. WELL SDTRK~ TREE= 7-1/16" CAMERONJm~ ~~ OFFWFIPSTOCK SE1' IN 9-5/8" CSG (NOT SHOWN). OLD ! WELLHEAD= MCEVOY Jml~.. J ~i, WELLBOREBELOW 9- 5/8" MLLOUTWINDOW NOT ON ACTUATOR= BAKERJ=~ V~'--~ DIAGRAM. WELL > 70 DEG @ 10725'. KB. ELEV = 68.68' Max Angle: 82 @ 10879' i 219Z' ~ 16" ClRCLLATION STRING I Datum IVD = 8800' $$ ~308' 20" CSG, 94/133#, H-40/K-55 1 13-3/0" cs~. 68#. Kss, ~ = 12.41,' ~ ~,~S' GAS LIFT MANDRELS Minimum ID 2.441" @ 10386' ST IvD '[VD DEV TYPE VLV LATCH PORT DATE 4-1/2" AVA DWP RETR. PATCH 6 2977 2969 16 KBG-2-LS DMY BTM 06/07/02 5 5449 5029 39 KBG-2-LS DMY BTM 06/07/02 4 7466 6432 42 KBG-2-LS BTM 3 8776 7378 43 KBG-2-LS BTM 2 9510 7915 43 KBG-2-LS BTM I 9-5/8" X 7" BKR PKR/TII:RACK, ID = 7.50" H 54~5' I 19-5/8"X7"BKRLNRH~R,'D=6.18" H 5479' ~ 110078 8323 43 KBG-2-LS BTM 9-5/8" MLLOUT WINDOW 5663' - 5703' ( OFF WHIPSTOCK) 1 9-5/8" csa, 47#, N-80, ~D: 8.681" I--I ~e3' I----" i I I I am04' ~4-1/2"HES X~. ~D= 3.813" ~ X I a0aa~' ~7"X4-1/~'~RS-a~,~.ID--3.O7S"I ! I I ao~as' ~4-1/2"HESX~P.~D=3.813" I I I10159' H~,-1/2"HESXNNIP, D:3.725"I 4-1/2" 'IBG, 12.6#, kS0, .0152 bp~, D :3.~58" 1016~' ~ I ~0~71' 4-1/2"WLEG, ID= 3.958" 17" L~R, 20~,13-CR-80, .O371bpf, ID: 6.184"H 1038~' I--~~ · ,~, ! ..... I I4-1/2"AVA DW' RETR. PATAK ID= 2.441" ~ j "U;:ht:~ r-JTOTAL LI3qGTH-- 35' 7" (08/17/97) I PERFORATION SUMMA RY RB: LOG: AWS BHCS 07/29/96 ANGLEATTOP PERF: 48 @ 10400' 121 80' J Note: Refer to ProduclJon DB for hislgrioal perf dala j S~TE SPF INTERVAL Opn/Sqz DATE 2.' 4 10400- 10410 C 08/17/97 Z' 4 11920- 11940 O 10/01/99 ' 3-3/8" 4 j 11960 - 11970 O 03/25/97 2-1/8'~ 4 12012- 12032 O 09129lg6 J 1.58" 4 12040- 12050 S 08/01/96 I 2'' 4 12090- 12110 O 10/01/99 3-3/8" 4 12125- 12145 O 03/25/97 2" 4 12140-12150 0 i09128196 J4-1/2"LNF~12.6#,13-O,.0152bpf, D=3.958"H 12283' J DATE REV BY COIVIVlENTS DATE ! REV BY COMIVENTS PRUDHOE BAY UNIT 11/09/77 ORIGINAL COMPLETION 06/07/02 RL/Ilh GLV UPDATE WELL: B-02A 08/19/96 RIG SIDETRACK PERIvIrr No: 1961110 01/29/01 SIS-SLT CONVERTEDTOCANVAS APINo: 50-029-20066-01 03/08/01 SIS~LG ,FINAL 961' SNL & 1598' WEL, Sec. 31, T111~ R14E 07/04/01 CH/KAK CORRECTIONS BP Exploration (Alaska) _~c. ANNED JUL SIZE SPF INTERVAL Opn/Sqz DATE Z' 4 10400- 10410 C 08/17/97 2" 4 11920- 11940 O 10/01/99 3-3/8" 4 11960 - 11970 O 03/25/97 2-1/8" 4 12012- 12032 0 09129196 1.58" 4 12040- 12050 S 08/01/96 Z' 4 12090- 12110 O 10/01/99 3-3/8" 4 12125- 12145 O 03/25/97 Z' 4 12140- 12150 O 09128/96 DATE REV BY COIVIVlENTS DATE REV BY COMIVENTS 11/09/77 ORIGINAL COMPLETION 06/07/02 RL/Ilh GLV UPDATE 08/19/96 RIG SIDETRACK 01/29/01 SIS-SLT CONVER'rEDTOCANVAS 03/08/01 SIS-LG FINAL 07/04/01 CI-I/KAK CORRECTIONS f?Glli© MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Julie Heusser, ~-. DATE: Commissioner THRU: Tom Maunder, P. I. Supervisor FROM: Jeff Jones, SUBJECT: Petroleum Inspector January 18, 2001 Safety Valve Tests Prudhoe Bay Unit B Pad Thursday, January 18, 2001' I traveled t© BPXs B Pad and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report shows I witnessed the testing of 17 wells and 34 components with 2 failures. The Pilot on well B-18 tripped below the required set point and the pilot on well B-21 was frozen. Both failures were repaired and sucessfully retested before I departed location. The new style pilot insulation box fabricated using pipeline insulation installed on most wells on this pad should be installed on the remaining SVS pilots to eliminate the freeze up problems evident on this pad. I also inspected the well houses on this pad while witnessing SVS testing. All the well houses inspected were clean and the equipment appeared to be in good cOndition. Summary: I witnessed the SVS testing at BPXs PBU B Pad PBU B Pad, 17 wells 34 components 2 failures 5.8% failure rate 22 well house inspections Attachment: SVS PBU B Pad 1-18-01 JJ X Unclassified Confidential Confidential (Unclassified if doc. removed ) SVS PBU B Pad 1-18-01 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF / PBU / B Pad, Separator psi: LPS 174 Date: 1/18/01 HPS 658 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE B-01 1700080 174 125 120 P P OIL B-02A 1961110!658/174 ~550/125 500/120 P P OIL B-03B 1870480 B-04 1700320 B-05A 1960990 B-06 1770740 174 125 120 P P OIL B-07 1780020 658 550 520 ~P P OIL B-08 1780410 658/174 550/125 510/110 P P OIL B-09 1780490 B-10 1780540 174 125 110 P P OIL B-11 1780690 · B-12A 1970090 658 550 530 P P OIL B-13A 1990570 B-14 1780930 B-15 1790190 B-16 1790250 B-.17 1790280 B-18 1820020 658 550i 0 3 P 1/18/01 OIL B-19 1820030 174 125 120 P P OIL B-20 1821680 174 125 120 P P OIL B-21 1821760 658 550 510 2 P 1/18/01 OIL B-22 1820890 B-23A 1970590 658/174 550/125 550/120 p P OIL B-24 1821400 B-25 1821510 174 125i 115 p p OIL B-26B 2000570 174 125 125 P P OIL B-27A 1961010 658/174 550/125 520/125 p P OIL B-28 1853030 B-29 1860140 B-30 1860310 B-31 1910460 IB-32A 1991180 B-33A 1931450 174 125 115 p p OIL B-34 1930370 1/19/01 Page 1 of 2 SVS PBU B Pad 1-18-01 JJ.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE B-35 19314601 B-36 1960650658/174 550/125 540/120 P P OIL J-05B 2000180 Wells: 17 Components: 34 Failures: 2 Failure Rate: 5.8% 1-19o var Remarks: The 2 failures were corrected and passed a retest. 1/19/01 Page 2 of 2 SVS PBU B Pad 1-18-01 JJ.xls PERMIT 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 96-111 AOGCC Individual Well Geological Materials Inventory DATA CCL SBT/GR DIFL-GR/SP BHC/GR CN/GR T DATA PLUS -- ~/5594-5750 ~00-4672 ~/10394-12276 ~0394-12245 .~'~10200-12184 ZDEN/CN/GR/CAL ~D/110394-12208 BOREHOLE PROF SSVD 7426 SBT PERF NGP-TVD NGP-MD 7939 TDTP 7640 7663 PATCH SET LEAK DETECT GR/CCL/JWL CHEM CUTT PATCH SET RCD ~0394-12208 ~/L/10394-12276 ,¢~io2oo-12276 ~ 10067-12163 ~12012-12160 ~:~/~212-9074 ~Im/5684-12283 ~3~S~ERRY GR ~10250-12180 ~f~SCHLT3M TDTP ~ SCHLUM TDTP ~10300-10594 ~10090-10620 ~0000-10480 L 10000-10480 ~L-~1024010530 Page: 1 Date: 08/12/98 RUN RECVD 1 07/19/96 1 07/19/96 i 08/12/96 1 08/12/96 1 08/12/96 1 08/12/96 1 08/12/96 1 08/12/96 1 08/30/96 FINAL 09/10/96 FINAL 10/25/96 FINAL 03/05/97 FINAL 03/05/97 2-6 03/20/97 FINAL 04/04/97 i 04/04/97 1 04/21/97 FINAL 05/02/97 FINAL 06/19/97 FINAL 08/28/97 FINAL 08/28/9.7 FINAL 10/20/97 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 2 Date: 08/12/98 RUN RECVD 10-407 ~OMPLETION DATE ~/~/ ~/ DAILY WELL OPS Are dry ditch samples Was the well cored? required? yes ~_And received? yes n~Analysis & description received? Are well tests required?~!yes Well is in compliance Received? COMMENTS -~'--- STATE OF ALASKA -- ALASKAL, ~ND GAS CONSERVATION COM. :;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [--] Operation Shutdown I--J Stimulate [] Plugging [~ Perforate [--]Pull Tubing l--lAIter Casing ~l Repair Well {~Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5.~T..,,ype 1~well: ~ ,~Development I I Exploratory E] Stratigraphic [~ Service 4. Location of well at surface 961' SNL, 1598' WEL, SEC. 31, T11 N, R14E At top of productive interval 1281' SNL, 3176' EWL, SEC. 32, T11N, R14E At effective depth 1765' SNL, 460' EWL, SEC. 32, T11 N, R14E At total depth 1787' SNL, 4915' EWL, SEC. 32, T11 N, R14E 6. Datum Elevation (DF or KB) KBE -- 68.50' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number B-02A 9. Permit Number / Approval No. 96-111 10. APl Number 50-029-20066-01 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12283 feet Plugs (measured) 9075 feet 12180 feet Junk (measured) 9039 feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented M D TVD Perforation depth: measured a sas Cons. Comr,nissio~ A~aska Oil ° :' ' Anchorage 11970'-11991 ';12012'-12032';12140'-12165'; (open) 10400'-10410';12040'-12050' true vertical 9000'-9004';9007'-9011 ';9030'-9035' (open)8654'-8654'; 9012'-9014' (squeeze) Tubing (size, grade, and measured depth) 4-1/2", 12.6# L-80 @ 10171' Packers and SSSV (type and measured depth) Packer @ 10115' SSSV @ 2204' 13. Stimulation or cement squeeze summary Intervals treated (measured) See attachment Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Represent~ive Daily Average Production orlniection Data Oil-Bbl Gas-Mcf Water-Bbl 1331 31 1458 2442 95 Casing Pressure Tubing Pressure 761 252 15. Attachments !16. Status of well classifications as: [] Copies of Logs and Surveys run _~. '~f"Oil F21r'4.~ I-1 E] Daily Report of Well Opera"~er.~o. ns-- .~,~' v., ....... ,.. ...... 17. ! he~~,that~ for~,/Ci~ng is tru~/a~ cCrrect to the best of my knowledge MICHAEEWIEUAMS .... '-'" -¢-'~-~v- Title Technical Assistant III Service Date Prepared By Name/Number'. Submit In Duplicate~~ Form 10-404 Rev. 06/15/88 B-02A ADDPERF 03/25/97 SUMMARY The following additional interval were perforated using 3 3/8" guns, 4 SPF, zero orientation and 0° phasing. 11960' -111970' MD REPERF 03/25/97 SUMMARY The following interval were reperforated using 3 3/8" guns, 4 SPF, zero orientation and 0° phasing. 12125'- 12145' MD TUBING PATCH 08/17/97 SUMMARY Set a AVA patch over the perforations @ 10,400' to 10,410'Rig up HB&R and PEAK and pump 250 bbls seawater to reduce well head pressure. Rig up Schlumberger and a 30' AVA patch. RIH. Tie in and set patch over the perforated interval. Pump the remaining 46 bbls of seawater to keep the WHP down. POH. Rig Down. POP well after the WHP comes back up. FLUIDS PUMPED BBLS DESCRIPTION 296 Seawater GeoQuest 500 W. International Airport Road Anchorage, Al(: 99518-1199 ATTH: Sherrle NO. 11457 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 10/16/97 Well Job # Log Description Date BL RF Sepia LIS Tape B-02A PATCH SETTING RECORD 970817 I 1 C- 16 PERFORATING/GR-CCL RECORD 970812 1 1 C-24 FULL SUITE PL W/PSP 97081 7 1 1 E-4 LEAK DETECTION LOG 970820 I 1 H-05 SPIN/PRESSFFEMP LOG W/PSP 97081 3 I 1 H- 07 POGLM SET RECORD 970824 I 1 H~I 3 SPIN/PRESSFFEMP LOG W/PSP 970813 1 1 H-17 BRIDGE PLUG SET RECORD 970818 I 1 H- 19 WHIPSTOCK SET RECORD 970828 1 1 H- 30 PERFORATE RECORD 970822 1 1 J-3 PERFORATION RECORD 970821 I 1 J- 18 PRODUCTION LOG 97081 4 I 1 M-09A RST 970822 I 1 M-24 STATIC PRESSURE TEMPERATURE 97081 8 I 1 N- 15 STATIC SURVEY-PRESS/TEMP 970813 1 1 Q-01 A PRODUCTION PROFILE 970830 I 1 R-12 LEAK DETECTION W/PSP 97081 9 I 1 R- 12 LEAK DETECTION W/PSP 970819 I 1 W-2 GRAVEL PACK LOG 970829 1 1 W- 18 PRODUCTION PROFILE 970830 1 1 bO' OIO -7~ .O-70 '7/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: OCT 1 G 199'~ Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 8/25/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11281 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape F-8 .'~-- ~"{~ .'~ 97344 CNTD 970521 1 1 1 A-26 DEPTH DETERMINATION GR/CCL 970704 1 1 A-41 PERFORATE RECORD 970708 1 1 B-02A GR COLLAR/JEWELRY LOG 97071 0 1 1 B-02 A CHEMICAL CUT RECORD 97071 0 1 1 B-12A WARM BACK LOG 97071 0 I 1 G- 15 PRODUCTION PROFILE LOG 970702 1 1 H- 13 PERFORATION RECORD 970702 1 1 M-25 LEAK DETECTION LOG 970703 1 1 INJECTION PROFILE 970706 1 1 U-09 U- 10 INJECTION PROFILE 9 70 701 I 1 W-06 TUBING CUT RECORD 97070 8 I 1 W- 23 LEAK DETECTION LOG 9 70 71 2 I 1 A-02 STATIC SURVEY 970707 I 1 W- 10 STATIC PRESSURE SURVEY 9 70 70 5 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED AUG 2 8 1997 Alaska Oil & Gas Cons. uommis~ And~orage Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~_L~ 6/18/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11097 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job Cf Log Description Date BL RF Sepia LIS Tape B-02A LEAK D D-1 EZSV S D-06 TUBING D-6 TUBING D-14 ORIEN1 G-03 TUBING M-05 JET CU' M-5 BACKO M-5 A/L 1 PERFOI M-11 TUBINE M-11 TUBINC. M-11 GAS LII N-1 - PRODU R-12 COMPL W-16 PRODU W-16 PRODU .-- 9N LOG 970527 I 1 )RD 970521 I 1 RECORD 970528 1 1 .., ~RECORD 970531 1 1 IHIPSTOCK 970516 1 1 RECORD 970529 I 1 [CORD 970507 I 1 )RD 970521 I 1 &BACKOFFRECORD 970523 1 1 RECORD 970518 1 1 RECORD 970519 I 1 'EY 970525 1 1 'ROFILE 970526 I 1 ECORD 970525 I 1 .OG 970517 1 1 .OG 970518 I 1 DETECTION SET REC PUNCH CU'FTER PUNCH CU'I-rER RECOI PATCH PATCH SUR' I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED JUN 1 9 199-/ · ~'a~ka 0il & Ga-s-C,6~ls, C~ Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~----"--~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10974 Company: FJeld: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 4/28/97 Well Job # Log Description Date BL RF Sepia LIS Tape B-2A PATCH SET RECORD 9 7 0 3 2 9 1 1 C- 17 PRODUCTION LOG 9 70 3 2 6 1 1 C-32 PRODUCTION PROFILE 9 70 3 2 3 1 1 M-09A JEWELRY LOG/GR/CCL 9 70 3 3 0 1 1 M-09A CBL 970331 1 1 M-09A PERFORATION RECORD 9 70 4 0 2 1 1 R-3 TUBING PATCH SE'l-rING RECORD 9 7 0 3 2 5 I 1 R-9 TUBING PATCH SETTING RECORD 9 7 0 3 2 4 I 1 S-4 INJ.PROFILE/TEMP.WARM BACK 9 7 0 3 2 7 I 1 $-14 INJECTION PROFILE LOG 9 70 3 2 2 1 1 S-24 INJ.PROFILE/TEMP.WARM BACK 9 70 3 2 3 1 1 S-44 PACKER SETTING RECORD 9 7 0 3 2 5 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Rece,ved by: GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10940 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 4/15/97 Well Job # Log Description Date BL RF Sepia LIS Tape B-2A "~- //Lp(_¢,.~. 97076 TDTP (REDO) 970206 1 N-21A --~ '~ b~ .~ (.p 97113 CNTD 970304 1 I I *NOTE: B-2A IS A "REDO" JOB . IT HAS BEEN EDITED TO ADDRESS: 1) A MISSING COMMENT STATEMENT IN FILE #2, & 2) INCORRECT PASS #/FILE # PAIRINGS. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10902 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape B-2A ~. ~ll.t)~o 97076 TDTP BORAX 970206 I I 1 N-20A d::~'-' 7(~,~-// 97112 CNTD 970304 I I 1 4/1/97 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500'W. International Airport Road Anchorage, Alaska 99618-1199 Received by.~~-,, 0 I~ I I--I-- I IXl G SEI=I~/I C E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 dS (,0 _ ( tl RE: MWD Formation Evaluation Logs - B-02A, AK-MW-60088 March 19, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20066-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company CI !::t I I-.I-- I IM i~ S E !:! ~./I I-' I~ S WELL LOG TRANSMITTAL To: State of Alaska March 5, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs B-02A, AK-MW-60088 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 B-02A: 2" x 5" MD Gamma Ray Logs: 50-029-20066-01 2" x 5" TVD Gamma Ray Logs: 50-029-20066-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company .... STATE OF ALASKA ALASl~-. ,.)IL AND GAS CONSERVATION CO,~,~VllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number _ BP Exploration (Alaska) Inc. 96-111 ' 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 .t~ 50-029-20066-01 4. Location of well at surface ri~~)~i 9. Unit or Lease Name 961'SNL, 1598' WEL, SEC. 31, T11N, R14E ! ' .' Prudhoe Bay Unit At top of productive interval ! ¢'.~...~/¢/4¢ ] '~J~-'-~JJ 10. Well Number 1281' SNL, 3176' EWL, SEC. 32, T11N, R14E ~- ~'~. !.~¢'~i. J B-02A Attotal depth ':~ i'.~::~'~)~ "~--~'~-~ '-~r'-. 11. Field and Pool 1787' SUE, 4915' EWE, SEC. 32, TllN, R14Ei ~:~-~-.,~_ .... ....~_ ? ..~.~-~ ii .~ Prudhoe Bay Field / Prudhoe Bay !5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE - 68.50'I ADL 028310 12. Date Spudded i13. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 07/13/96 07/26/96 09/28/96 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+'I-VD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 12283 9075 F-r1 12180 9039 F~ I~Yes i-INo I (Nipple) 2204' MD/ 1900' (Approx.) 22..Type Electric or Other Logs Run MWD, CBL, GR, CCL, SBT, DIR-GR, DIFL, SP, Temp, BHC-Acoustilog, CN, ZDL 23. CASING, LINER AND CEMENTING RECORD CASING SE-I-rING DEPTH HOLE SIZE VVT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED See Attached 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 4 spf 1.7" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10171' 101 15' MD TVD MD TVD 11970' - 11991' 9000' - 9004' Sqzd 12012' - 12032' 9007' - 9011' 10400' - 10410' 8654' - 8654' 26. ACI'D, FRACTURE, CEMENT SQUEEZE, ETC. 12140'- 12165' 9030'- 9035' Sqzd DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12040' - 12050' 9012' - 9014' 11755' - 12193' Perf 2 Intvls (Gun Dia., 1.7", 4 spf); 70 Bbls Acid Sweep 12040' - 12050' & Cmt Sqz to finish cmt job for 4-1/2" Liner;, 35 Bbls ORIGINAL 10400' - 10410' 'G', Sqzd at 4000 psi; 15 Bbls 'G', Sqzd at 3000 psi Freeze Protect w/150 Bbls Diesel 27. PRODUCTION TEST Date First Production 1Method of Operation (Flowing, gas lift, etc.) September 28, 1996 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SiZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing !Casing PressureCALCULATED ~ OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORE) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED r',(' T A]ask,?, 0il & 6as Cot, s, Co!'nmissior: Anc Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Mark¢._ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name' Depth Depth and gravity, GOR, and time of each phase. Sag River 10226' 8500' _- Shublik 10268' 8531' Top of Sadlerochit 10385' 8613' Zone 4A 10556' 8721' Zone 3 10900' 8828' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that/~regoing i~,t~ a,~i.,,~orrect to the best of my knowledge Signed D~,~Sto~ ,~/~-~.~ ~ Title Senior Drilling Engineer Date ,/',~ .~ ~-~/-~ Prepared By Name/Number: 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, W~.te~r,.:ln~,ctioC),'!~.'lia'~ction, Shut-In, Other-explain. ~"~ ~.~ ~.~. ':-. ~ ~' ...... ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL NAME: B-02A 23. Attachment - Casing, Liner and Cementing Record Casing Setting Depth Hole Size Wt. Per Ft. Grade Top Bottom Size Cementing Record 30" Stove Pipe Surface 107' 36" 150 sx Permafrost 20" 94# / 133# H-40 / K-55 Surface 2308' 26" 5100 sx Permafrost 16" 65# H-40 Surface 2192' N/A Circulating, Not Cemented 13-3/8" 61# / 68# H-40 / K-55 Surface 4545' 17-1/2" 1200 sx Class 'G' 9-5/8" 47# L-80 Surface 1968' 12-1/4" 3530 sx Class 'G' 10-3/4" 55.5# K-55 1968' 2380' 12-1/4" 9-5/8" 47# N-80 2380' 5663' 12-1/4" 7" 29# 13Cr/L-80 5465' 10385' 8-1/2" 225 sx Class 'G' 4-1/2" 12.6# 13Cr 10174' 12283' 6" 66 sx Class 'G', 168 sx Class 'G' SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: B-02A Rig Name: Doyon 16 AFE: 4P0833 Accept Date: 07/01/96 Spud Date: 07/1 3/96 Release Date: 08/1 9/96 Jul I 1996 (1) Rig moved 100 %. Rigged up Bulk system. Retrieved Hanger plug. Jul 2 1996 (2) Retrieved Hanger plug. Held safety meeting. Rigged up High pressure lines. Circulated at 5859 ft. Installed BOP test plug assembly. Removed Xmas tree. Rigged up BOP stack. Tested BOP stack. Retrieved BOP test plug assembly. Installed Drillpipe retrieval string. Pulled Tubing on retrieval string to 5859 ft. Circulated at 5859 ft. Laid down 2990 ft of Tubing. Rigged up Service lines. Laid down 400 ft Of' Tubing. Jul 3 1996 (3) Held safety meeting. Laid down 5859 ft of Tubing. Rigged down Tubing handling equipment. Rigged up Wireline units. Rigged up sub-surface equipment - Bridge plug. Tested Casing. Rigged up sub-surface equipment - Survey instruments. Rigged down Surveywireline unit. Rigged up BOP stack. Removed Casing spool. Rigged up BOP stack. Tested BOP stack. Rigged up Wireline units. Ran electric logs. Jul 4 1996 (4) Ran electric logs. Ran electric logs. Rigged down Wireline units. Made up BHA no. 1 . Singled in drill pipe to 1940 ft. Functioned downhole tools at 1940 ft. Circulated at 1940 ft. Pulled out of hole to 0 ft. Installed Drillpipe retrieval string. Worked toolstring at 25 ft. Rigged down BOP stack. Functioned downhole tools at 402 ft. Jul 5 1996 (5) Functioned downhole tools at 402 ft. Pulled out of hole to 0 ft. Pulled Casing on retrieval string to 402 ft. Rigged down BOP stack. Circulated at 402 ft. Pulled Casing on retrieval string to 402 ft. Rigged down BOP stack. Pulled Casing on retrieval string to 402 ft. Rigged up Casing handling equipment. Laid down 402 ft of Casing. Rigged down BOP stack. Installed Casing spool. Rigged up BOP stack. Tested BOP stack. Made up BHA no. 2. Fished at 402 ft. Operations Summary for: E _'A Jul 6 1996 (6) Jarred stuck pipe at 402 ft. Circulated at 1940 ft. Fished at 402 ft. Circulated at 1940 ft. Rigged up Steam heat exchanger. Acid job - 60 bbl acid pumped at 225 psi, conc. = 15 %, press. Soak. Displace treatment. Circulated at 1940 ft. Pumped out of hole to 402 ft. Pulled BHA. Rigged up Casing handling equipment. Jul 7 1996 (7) Held safety meeting. Laid down 1538 ft of C~.sing. Rigged down Casing handling equipment. Tested Casing. Made up BHA no. 3. R.I.H. to 483 ft. Jarred stuck pipe at 483 ft. Pulled BHA. Made up BHA no. 4 . Serviced Electromagnetic brake. Jarred stuck pipe at 519 ft. Jul 8 1996 (8) Held safety meeting. Jarred stuck pipe at 1940 ft. Circulated at 1940 ft. Pulled out of hole to 375 ft. Pulled BHA. R.I.H. to 2468 ft. Circulated at 2468 ft. Pulled out of hole to 0 ft. Made up BHA no. 6 . R.I.H. to 450 ft. Held safety meeting. R.I.H. to 1880 ft. Serviced Block line. Rigged up Wireline units. Prepared & fired cutting charge at 1968 ft. Fished at 1968 ft. Pulled out of hole to 479 ft. Pulled BHA. Made up BHA no. 7. R.I.H. to 2316 ft. Jul 9 1996 (9) Functioned downhole tools at 1968 ft. Pulled out of hole to 0 ft. R.I.H. to 1940 ft. Fished at 1940 ft. Pulled out of hole to 0 ft. R.I.H. to 1968 ft. Functioned downhole tools at 1968 ft. Pulled out of hole to 0 ft. Held safety meeting. R.I.H. to 1940 ft. Fished at 1940 ft. Serviced Draw works. Fished at 1940 ft. Circulated at 1968 ft. Pulled out of hole to 0 ft. Rigged up Casing handling equipment. Ran Casing to 350 ft (9.625 in OD). Jul 10 1996 (10) Held safety meeting. Ran Casing to 1940 ft (9.625 in OD). Worked toolstring at 1940 ft. Circulated at 11940 ft. Rigged up Casing handling equipment. Laid down 1940 ft of Casing. Rigged down. Casing handling equipment. Rigged up sub-surface equipment - Hole opener. Held safety meeting. Ran Drillpipe in stands to 925 ft. Serviced SCR. Ran Drillpipe in stands to 1940 ft. Singled in drill pipe to 1967 ft. Washed to 1967 ft. Pulled out of hole to 365 ft. Laid down 365 ft of Drill collar. Rigged up Casing handling equipment. Ran Casing to 530 ft (9.625 in OD). Jul 11 1996 (11) Held safety meeting. Ran Casing to 1968 ft (9.625 in OD). Circulated at 1967 ft. Ran Casing to 1968 ft (9.625 in OD). Tested Other sub-surface equipment - Via string. Rigged up All-functions. Rigged up Sub sea tools. Rigged up Sub sea tools. Held safety meeting. Rigged up Sub sea tools. Held drill (Fire). Rigged up All functions. Tested All functions. Page 2 Operations Summary for: [- _'A Jul 12 1996 (12) Held safety meeting. Tested All functions. Rigged up Drillstring handling equipment. R.I.H. to 360 ft. Rigged down Kelly/top drive hose. Made up BHA no. 8 · R.I.H. to 2000 ft. Rigged up Kelly/top drive hose· Held safety meeting. Held drill (Spill). Singled in drill pipe to 5679 ft. Circulated at 5679 ft. Tested Other sub- surface equipment - Via string. Pulled out of hole to 0 ft. Made up BHA no. 9. Jul 13 1996 (13) Held safety meeting. R.I.H. to 5693 ft. Set tool face. Milled Other sub-surface equipment at 5700 ft. Held safety meeting. Milled Other sub-surface equipment at 5703 ft. Circulated at 5703 ft. Held drill (Kick while drilling). Flow check. Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 10 . R.I.H. to 800 ft. Functioned downhole tools at 800 ft. R.I.H. to 2000 ft. Functioned downhole tools at 2000 ft. Jul 14 1996 (14) Held safety meeting. R.I.H. to 5630 ft. Set tool face. Drilled to 6066 ft. Held drill (Spill). Drilled to 6097 ft. Held safety meeting. Drilled to 6624 ft. Held drill (Fire). Circulated at 6624 ft. Flow check. Pulled out of hole to 5700 ft. Jul 15 1996 (15) Held safety meeting. Drilled to 7164 ft. Held drill (Fire). Drilled to 7246 ft. Held safety meeting. Drilled to 7646 ft. Circulated at 7646 ft. Flow check. Pulled out of hole to 5700 ft. Held drill (Kick while tripping). R.I.H. to 7646 ft. Drilled to 7862 ft. Jul 16 1996 (16) Held safety meeting. Drilled to 8361 ft. Held drill (H2S). Drilled to 8609 ft. Held safety meeting. Drilled to 8671 ft. Circulated at 8671 ft. Flow check. Pulled out of hole to 7543 ft. R.I.H. to 8671 ft. Drilled to 8921 ft. Held drill (Kick while drilling). Drilled to 9200 ft. Jul 17 1996 (17) Held safety meeting. Drilled to 9698 ft. Held drill (Spill). Circulated at 9698 ft. Flow check. Pulled out of hole to 8570 ft. R.I.H. to 9698 ft. Held safety meeting. Drilled to 10100 ft. Jul 18 1996 (18) Held safety meeting. Drilled to 10385 ft. Held drill (Spill). Circulated at 10385 ft. Held safety meeting. Circulated at 10385 ft. Pulled out of hole to 5663 ft. Serviced Block line. R.I.H. to 10385 ft. Circulated at 10385 ft. Flow check. Pulled out of hole to 8870 ft. R.I.H. to 10385 ft. Circulated at 10385 ft. Page Operations Summary for: B ,A Jul 19 1996 (19) Held safety meeting. Flow check. Pulled out of hole to 0 ft. Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 160 ft (7 in OD). Held safety meeting. Ran Casing to 4900 ft (7 in OD). Circulated at 4900 ft. Ran Drillpipe to 5618 ft (5 in OD). Circulated at 5618 ft. Ran Drillpipe to 7200 ft (5 in OD). Jul 20 1996 (20) Held safety meeting. Ran Casing to 10385 ft (7 in OD). Circulated at 10385 ft, Held safety meeting. Mixed and pumped slurry - 47 bbl. Reverse circulated at 5450 ft. Flow check. Held drill (Fire). Laid down 5450 ft of Drillpipe. Tested All functions. Held safety meeting. Tested BOP stack. Laid down 850 ft of Drillpipe. Made up BHA no. 11 . R.I.H. to 3000 ft. Held drill (Kick while tripping). R.I.H. to 4500 ft. Jul 21 1996 (21) Held safety meeting. R.I.H. to 10276 ft. Drilled cement to 10303 ft. Circulated'at 10303 ft. Tested Other sub-surface equipment - Via string. Held drill (Kick (well kill)). Drilled cement to 10395 ft. Circulated at 10395 ft. Held safety meeting. Circulated at 10395 ft. Held drill (H2S). Drilled to 10678 ft. Jul 22 1996 (22) Held safety meeting. Drilled to 10746 ft. Flow check· Pulled out of hole to 0 ft. Pulled BHA. R.I.H. to 1000 ft. Held drill (Kick while tripping). R.I.H. to 4000 ft. Held safety meeting. R.I.H. to 10706 ft. Drilled to 10820 ft. Held drill (Kick while drilling). Drilled to 10896 ft. Jul 23 1996 (23) Held safety meeting· Drilled to 11016 ft. Held drill (Spill). Drilled to 11067 ft. Circulated at 11067 ft. Held safety meeting. Rest hole at 11067 ft. Drilled to 11093 ft. Circulated at 11093 ft. Drilled to 11203 ft. Held drill (Fire). Circulated at 11203 ft. Jul 24 1996 (24) Held safety meeting· Rest hole at 11203 ft. Flow check. Pulled out of hole to 10385 ft. Rest hole at 10385 ft. Circulated at 10385 ft. Held drill (H2S). Pulled out of hole to 6000 ft. Held safety meeting. Pulled out of hole to 0 ft. Made up BHA no. 13. R.I.H. to 300 ft. Tested M.W.D. tool- Via string. R.I.H. to 10385 ft. Held drill (Spill). Serviced Block line. Circulated at 10385 ft. R.I.H. to 11100 ft. Jul 25 1996 (25) Held safety meeting. Reamed to 11203 ft. Drilled to 11492 ft. Worked toolstring at survey11492 ft.at 1Pulled1168 ft.°ut of hole to 0 ft. Made up BHA no. 14 R.I H. t72~!~(~4~,~;~, i:.:.~: '~-~ ~'!' ~J ~_~, U Page 4 Operations Summary for: E A Jul 26 1996 (26) Held safety meeting. Drilled to 12283 ft. Circulated at 12283 ft. Pulled out of hole to 10385 ft. Jul 27 1996 (27) Held safety meeting. Pulled out of hole to 10385 ft. Circulated at 12283 ft. Circulated at 10385 ft. Pulled out of hole to 10385 ft. Rest hole at 10385 ft. Pulled out of hole to 186 ft. Pulled BHA. Rigged up Logging/braided cable equipment. Ran Drillpipe in stands to 9975 ft. Rigged up sub-surface equipment - Formation logs. Pulled Drillpipe in stands to 2535 ft. Jul 28 1996 (28) Pulled Drillpipe in stands to 118 ft. Rigged down sub-surface equipment - Formation logs. Retrieved Wear bushing. Tested BOP stack. Installed Wear bushing. Made up BHA no. 15. R.I.H. to 9325 ft. Held safety meeting. R.I.H. to 10325 ft. Serviced Block line. Circulated at 10325 ft. R.I.H. to 12234 ft. Reamed to 12283 ft. Circulated at 12283 ft. Pulled out of hole to 10325 ft. Circulated at 10325 ft. Pulled out of hole to 9209 ft. Jul 29 1996 (29) Held safety meeting. Pulled out of hole to 205 ft. Pulled BHA. Rigged up sub-surface equipment- Formation logs. Ran Drillpipe in stands to 9975 ft. Rigged up sub-surface equipment - Other sub-surface equipment. Ran Drillpipe in stands to 10385 ft. Ran electric logs. Rigged down sub-surface equipment - Other sub-surface equipment. Pulled out of hole to 7065 ft. Jul 30 1996 (30) Held safety meeting. Pulled out of hole to 118 ft. Rigged down sub-surface equipment - Formation logs. Rigged up Casing handling equipment. Ran Casing to 2110 ft (4.5 in OD). Circulated at 2110 ft. Ran Drillpipe in stands to 3970 ft. Held safety meeting. Ran Drillpipe in stands to 10385 ft. Circulated at 10385 ft. Ran Drillpipe in stands to 12283 ft. Circulated at 12283 ft. Mixed and pumped slurry - 55 bbl. Rigged down sub-surface equipment - Other sub-surface equipment. Pulled Drillpipe in stands to 7848 ft. Jul 31 1996 (31) Held safety meeting. Pulled Drillpipe in stands to 0 ft. Rigged up Drillstring handling equipment. Made up BHA no. 16. R.I.H. to 9034 ft. Held safety meeting. R.I.H. to 9725 ft. Laid down 2738 ft of 3.5 in OD drill pipe. Serviced Block line. R.I.H. to 10162 ft. Washed to 10194 ft. Drilled cement to 10215 ft. Serviced Mud pump fluid end. Worked toolstring at 10155 ft. Page 5 Operations Summary for: B ~ Aug I 1996(32) Held safety meeting. Pulled out of hole to 355 ft. Pulled BHA. Made up BHA no. 16. R.I.H. to 7550 ft. Held safety meeting. R.I.H. to 10159 ft. Drilled cement to 10501 ft. Aug 2 1996 (33) Drilled cement to 10717 ft. Circulated at 10717 ft. Pulled out of hole to 10145 ft. Drilled cement to 11213 ft. Circulated at 1121~3 ft. Pulled out of hole to 10150 ft. Circulated at 10150 ft. Aug 3 1996 (34) Circulated at 10150 ft. R.I.H. to 11213 ft. Drilled cement to 11739 ft. Circulated at 11739 ft. Pulled out of hole to 10170 ft. Drilled cement to 12047 ft. Aug 4 1996 (35) Drilled cement to 12191 ft. Circulated at 12191 ft. Laid down 2015 ft of 5 in OD drill pipe. Pulled out of hole to 4500 ft. Held safety meeting. Pulled out of h°le to 356 ft. Pulled BHA. Rigged down sub-surface equipment - Formation logs. Ran Tubing to 2210 ft (2.875 in OD). Ran Drillpipe in stands to 5200 ft. Aug 5 1996 (36) Held safety meeting. Ran Drillpipe in stands to 10001 ft. Rigged up sub-surface equipment - Drilling tool/logs. Ran electric logs. Rigged down sub-surface equipment- Drilling tool/ logs. Serviced Block line. Held safety meeting. Pulled Drillpipe in stands to 75 ft. Rigged down sub-surface equipment - Drilling tool/logs. Tested BOP stack. Aug 6 1996 (37) Tested BOP stack. Installed Wear bushing. Ran Drillpipe in stands to 12065 ft. Tested Casing - Via string. Rigged up Logging/braided cable equipment. Perforated. Perforated from 12045 ft to 12050 ft. Circulated at 12050 ft. Circulated at 12065 ft. Pulled Drillpipe in stands to 6445 ft. Aug 7 1996 (38) Held safety meeting. Pulled Driilpipe in stands to 1888 ft. Laid down 1888 ft of Tubing. Rigged up sub-surface equipment - Cement retainer. Ran Drillpipe in stands to 10962 ft. Packer worked at 10962 ft. Set packer at 10962 ft with 0 psi. Injectivity test - 60 bbl injected at 2200 psi. Circulated at 10962 ft. Injectivity test - 5 bbl injected at 2500 psi. Circulated at 10962 ft. Pulled Drillpipe in stands to 0 ft. Rigged up Wireline units. Perforated from 10400 ft to 10405 ft. Rigged down Wireline units. Rigged up sub-surface equipment - Cement retainer. Ran Drillpipe in stands to 3487 ft. Serviced Block line. Page Operations Summary for: B A Aug 8 1996 (39) Held safety meeting. Ran Drillpipe in stands to 10764 ft. Circulated at 10962 ft. Circulated at 10960 ft. Held safety meeting. Mixed and pumped slurry - 44 bbl. Circulated at 10960 ft. Held safety meeting. Circulated at 10960 ft. Circulated at 12045 ft. Held safety meeting. Mixed and pumped slurry - 37 bbl. Pulled Drillpipe in stands to 10177 ft. Aug 9 1996 (40) Held safety meeting. Circulated at 10177 ft. Pulled Drillpipe in stands to 821 ft. Held drill (Kick while tripping). Pulled Drillpipe in stands to 0 ft. Ran Drillpipe in stands to 821 ft. Held safety meeting. Ran Drillpipe in stands to 8296 ft. Held drill (Kick while tripping). Ran Drillpipe in stands to 10177 ft. Circulated at 10257 ft. Washed to 10332 ft. Laid down 756 ft of Drillpipe. Washed to 10425 ft. Aug 10 1996 (41) Held safety meeting. Washed to 10456 ft. Circulated at 10456 ft. Washed to 10961 ft. Held safety meeting. Washed to 10961 ft. Washed to 11338 ft. Washed to 11537 ft. Held drill (Fire). Washed to 11845 ft. Aug 11 1996 (42) Held safety meeting. Washed to 12193 ft. Circulated at 12193 ft. Injectivity test - 11.5 bbl injected at 1700 psi. Flow check. Pulled Drillpipe in stands to 10177 ft. Circulated at 10177 ft. Held safety meeting. Circulated at 10177 ft. Pulled out of hole to 0 ft. Ran Tubing to 90 ft (2.875 in OD). Held drill (H2S). Ran Tubing to 2000 ft (2.875 in OD). Aug 12 1996 (43) Held safety meeting. Ran Drillpipe in stands to 10177 ft. Rigged up sub-surface equipment - Production logging tools. Ran Drillpipe in stands to 12190 ft. Rigged down sub-surface equipment - Production logging tools. Held drill (Fire). Serviced Block line. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Laid down 60 ft of Tubing. Ran Drillpipe in stands to 10200 ft. Aug 13 1996 (44) Held safety meeting. Ran Drillpipe in stands to 12050 ft. Held safety meeting. Rigged up sub-surface equipment - Perforating tools. Flow check. Pulled Drillpipe in stands to 10410 ft. Perforated from 10400 ft to 10410 ft. Ran Drillpipe in stands to 12170 ft. Held drill (Kick while tripping). Circulated at 12170 ft. Held safety meeting. Circulated at 12170 ft. Flow check. Pulled Drillpipe in stands to 1800 ft. Laid down 1730 ft of Tubing. Held drill (Spill). Ran Drillpipe in stands to 4000 ft. Page 7 Operations Summary for: B A Aug 14 1996 (45) Held safety meeting. Ran Drillpipe in stands to 11755 ft. Set packer at 11755 ft with 0 psi. Held safety meeting. Circulated at 11755 ft. Acid job - 70 bbl acid pumped at 1000 psi, conc.- 15 %, press. Circulated at 11755 ft. Held safety meeting. Circulated at 11755 ft. Pulled Drillpipe in stands to 11571 ft. Circulated at 11571 ft. Pulled Drillpipe in stands to 10190 ft. Circulated at 10190 ft. Flow check. Pulled Drillpipe in stands to 6300 ft. Held drill (H2S). Pulled Drillpipe in stands to 0 ft. Tested All functions. Aug 15 1996 (46) Held safety meeting. Tested All functions. Held safety meeting. Rigged down Kill manifold. Held safety meeting. Tested High pressure lines. Made up BHA no. 20. R.I.H. to 10157 ft. Serviced Block line. Circulated at 10177 ft. R.I.H. to 11585 ft. Drilled to 11686 ft. Held drill (Kick while drilling). Drilled to 11745 ft. Aug 16 1996 (47) Held safety meeting. Circulated at 11746 ft. Circulated at 11746 ft. Drilled cement to 11755 ft. Drilled installed equipment - Cement retainer. Drilled cement to 12030 ft. Held drill (H2S). Drilled cement to 12118 ft. Held safety meeting. Drilled cement to 12180 ft. Circulated at 12180 ft. Pulled out of hole to 0 ft. Pulled BHA. Held drill (Spill). R.I.H. to 7500 ft. Aug 17 1996 (48) Held safety meeting. Flow check. Pulled out of hole to 5465 ft. R.I.H. to 10177 ft. Milled Tie back packer at 10177 ft. Set Tie back packer at 10177 ft with 0 psi. Circulated at 10177 ft. Flow check. Pulled out of hole to 0 ft. Held drill (Fire). R.I.H. to 2000ft. Held safety meeting. R.I.H. to 10177 ft. Set Tie back packer at 10167 ft with 0 psi. Tested Tie back packer- Via annulus. Flow check. Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 23. Aug 18 1996 (49) Held safety meeting. R.I.H. to 12180 ft. Reverse circulated at 12180 ft. Held drill (Spill). Flow check. Laid down 2100 ft of 5 in OD drill pipe. Serviced Block line. Laid down 2000 ft of 5 in OD drill pipe. Held safety meeting. Laid down 2000 ft of 5 in OD drill pipe. Laid down 4000 ft of 3.5 in OD drill pipe. Held drill (Kick while tripping). Laid down 2000 ft of 2.875 in OD drill pipe. Rigged up Completion string handling equipment. Held safety meeting. Ran Tubing to 800 ft (4.5 in OD). Aug 19 1996 (50) Held safety meeting. Ran Tubing to 10170 ft (4.5 in OD). Space out tubulars. safety meeting. Tested Dual control line. Set packer at 10115 ft with 4000 psi. up High pressure lines. Rigged down All functions. Held Rigged Page 8 Operations Summary for: £ .A Aug 20 1996 (51) Held safety meeting. Rigged down All functions. Rigged up Production master - surface tree. Rigged down Lubricator. Rigged down High pressure lines. Rigged down High pressure lines. Rigged down Sand traps. Page 9 B-02A DESCRIPTION OF WORK COMPLETED NRWO / PERF ! ADPERF / REPERF 09/14/96 A Bullhead Cement Squeeze was performed using the following fluids: SUMMARY Unable to bullhead seawater into well- looked like the perfs were locking up. On the CTU pressure test on 9/7, bullheading was easy, so some debris must have gotten into perfs during that bullhead and the early part of this one. Did a circulation kill from TD. Got injectivity of 1 bpm at 1300 psi WHP. Pumped 10 bbls 10% HCI and got injecti¥ity of 1 bpm at 500 psi. Layed in 15 bbls cement from 100 ft below the upper perfs and built squeeze pressure to 3000 psi. When pumping stopped WHP gradually dropped off and we couldn't get a pressure test. Estimated from returns that we were losing 0.1 bpm which is similar to what we were seeing going to the lower perfs during the pressure test on 9/7. More likely this was cement moving down to the lower perfs than going behind the liner at the upper perfs. During reverse out we hit hard cement 190 ft below the depth we layed it in. The cement in the bath (165 degrees) had not yet set up. The cement probably was moving down towards the slightly leaking lower perfs and hit a higher temperature or mixed with seawater and set early. We were able to jet through with dual polymer. Continued to contaminate and reversed out contaminant. Jetted the cemented interval. Jetted the jewelery and GLMs on the way out. Estimate 10 bbls cement returned. The final pressure test to 2250 psi dropped 100 psi in 10 minutes and was still gradually falling so there is still a very small leak, again probably the bottom perfs. 10400' - 12050' FLUIDS PUMPED BBLS DESCRIPTION 8 Methanol 20 Dual polymer 10 10% HOL 15 Cement 1 9 Freshwater 990 Seawater B-02A, Post-Rig We Page 2 O9/28/96 The following initial intervals were perforated using 2.125" guns, 4 SPF, random orientation and 180° phasing. 12012' - 12032' 12140'- 12160' 10/13/96 The following additional intervals were perforated using 3 3/8" guns, 4 SPF, random orientation and 60/120° phasing. 11970' - 11991' 12144' - 12165' 10-13-96 The following interval was reperforated using 3 3/8" guns, 4 SPF, random orientation and 60/120° phasing. 12012' - 12032' RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / B-02A 50029200601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 DATE OF SURVEY: 072696 MWD SURVEY JOB NUMBER: AK-MW-60088 KELLY BUSHING ELEV. = 68.50 FT. OPERATOR: BP EXPLOKATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5650.00 5185.90 5117.40 5663.00 5196.04 5127.54 5839.13 5328.64 5260.14 5869.86 5350.79 5282.29 5900.09 5372.59 5304.09 38 47 S 74.66 E .00 300.44S 1510.47E 38 39 S 74.66 E 1.00 302.59S 1518.31E 43 54 S 88.50 E 5.96 318.79S 1632.73E 43 48 S 86.60 E 4.29 319.70S 1654.00E 43 55 S 87.30 E 1.65 320.81S 1674.92E 1529.00 1537.12 1650.91 1671.40 1691.63 5931.42 5395.08 5326.58 5963.18 5417.73 5349.23 5994.11 5439.68 5371.18 6085.78 5504.41 5435.91 6180.54 5570.65 5502.15 44 19 S 87.00 E 1.41 321.90S 1696.71E 44 41 S 89.80 E 6.29 322.52S 1718.95E 44 52 S 89.10 E 1.70 322.73S 1740.74E 45 17 N 88.50 E 1.91 322.38S 1805.64E 46 0 N 88.20 E .77 320.43S 1873.37E 1712.67 1734.01 1754.78 1816.36 1880.12 6273.13 5635.88 5567.38 6365.59 5702.22 5633.72 6459.97 5770.11 5701.61 6552.98 5836.96 5768.46 6645.41 5903.21 5834.71 44 24 N 87.00 E 1.96 317.69S 1939.00E 43 54 N 87.40 E .62 314.54S 2003.33E 44 5 N 87.70 E .31 311.74S 2068.83E 44 0 S 89.50 E 2.10 310.72S 2133.47E 44 26 S 89.50 E .48 311.28S 2197.93E 1941.65 2001.80 2063.18 2124.30 2185.74 6738.42 5969.69 5901.19 6833.14 6037.22 5968.72 6926.09 6103.65 6035.15 7017.44 6169.48 6100.98 7110.98 6236.79 6168.29 44 18 S 89.60 E .16 311.80S 2262.97E 44 44 N 89.60 E .75 311.79S 2329.39E 44 1 N 89.60 E .77 311.34S 2394.40E 43 45 N 90.00 E .42 311.12S 2457.73E 44 12 S 88.70 E 1.08 311.86S 2522.68E 2247.72 2310.84 2372.48 2432.60 2494.56 7201.99 6301.80 6233.30 7298.44 6373.01 6304.51 7388.17 6441.34 6372.84 7482.33 6512.46 6443.96 7575.87 6582.46 6513.96 44 35 S 89.60 E .81 312.80S 2586.35E 40 12 N 89.80 E 4.58 312.93S 2651.37E 40 35 N 89.00 E .73 312.32S 2709.52E 41 17 N 89.50 E .82 311.51S 2771.23E 41 47 N 88.90 E .68 310.64S 2833.26E 2555.37 2617.21 2672.28 2730.68 2789.37 7667.16 6650.14 6581.64 7760.09 6718.33 6649.83 7853.93 6786.42 6717.92 7948.65 6854.36 6785.86 8040.99 6919.98 6851.48 42 30 N 89.60 E .92 309.85S 2894.52E 43 5 N 89.20 E .71 309.18S 2957.65E 43 50 N 89.00 E .81 308.17S 3022.21E 44 30 N 89.80 E .90 307.48S 3088.21E 44 54 N 89.70 E .45 307.20S 3153.17E 2847.34 2907.13 2968.17 3030.69 3092.33 8134.87 6987.15 6918.65 8228.25 7054.82 6986.32 8320.26 7121.49 7052.99 8413.46 7188.61 7120.11 8505.89 7254.73 7186.23 43 43 N 90.00 E 1.29 307.02S 3218.75E 43 24 S 89.80 E .36 307.13S 3283.10E 43 42 N 90.00 E .36 307.24S 3346.51E 44 9 S 88.30 E 1.35 308.21S 3411.15E 44 30 S 89.70 E 1.12 309.33S 3475.72E 3154.61 3215.81 3276.10 3337.84 3399.55 ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / B-02A 50029200601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 DATE OF SURVEY: 072696 MWD SURVEY JOB NUMBER: AK-MW-60088 KELLY BUSHING ELEV. = 68.50 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8601.26 7322.70 7254.20 8694.50 7388.86 7320.36 8788.23 7456.10 7387.60 8883.17 7525.65 7457.15 8976.25 7594.44 7525.94 44 35 45 0 43 17 42 30 42 12 S 89.30 E .31 309.92S 3542.62E S 89.20 E .44 310.78S 3608.32E S 89.70 E 1.85 311.41S 3673.59E N 89.40 E 1.06 311.24S 3738.22E S 88.90 E 1.27 311.51S 3800.91E 3463.32 3526.02 3588.26 3649.63 3709.30 9067.00 7661.51 7593.01 9159.97 7729.78 7661.28 9251.92 7796.86 7728.36 9343.74 7863.41 7794.91 9438.33 7932.08 7863.58 42 30 43 0 43 17 43 47 43 5 N 89.60 E 1.16 311.88S 3862.04E S 89.00 E 1.16 312.22S 3925.14E S 89.00 E .33 313.32S 3988.02E S 88.10 E .87 314.92S 4051.26E N 89.60 E 1.83 315.78S 4116.29E 3767.51 3827.59 3887.69 3948.29 4010.36 9533.14 8001.13 7932.63 9625.66 8067.97 7999.47 9722.51 8137.28 8068.78 9814.90 8202.89 8134.39 9906.41 8268.10 8199.60 43 24 44 5 44 30 45 0 44 5 N 88.50 E .86 314.70S 4181.24E N 88.80 E .79 313.19S 4245.20E N 89.00 E .44 311.90S 4312.83E S 89.00 E 1.62 311.90S 4377.86E S 89.90 E 1.20 312.52S 4442.05E 4071.76 4132.07 4195.95 4257.76 4318.96 9998.65 8334.84 8266.34 10089.80 8401.29 8332.79 10183.60 8469.55 8401.05 10277.96 8537.72 8469.22 10313.90 8563.46 8494.96 43 12 43 12 43 24 44 5 44 24 S 89.10 E 1.14 313.07S 4505.72E S 89.50 E .30 313.83S 4568.11E S 88.60 E .69 314.90S 4632.43E S 88.50 E .75 316.55S 4697.65E S 88.30 E .92 317.25S 4722.72E 4379.63 4439.17 4500.63 4563.14 4587.18 10445.42 8654.32 8585.82 10476.64 8674.65 8606.15 10507.30 8693.59 8625.09 10538.73 8711.71 8643.21 10569.47 8728.23 8659.73 48 12 50 30 53 12 56 24 58 35 S 85.80 E 3.20 322.21S 4817.65E S 82.90 E 10.19 324.55S 4841.21E S 80.50 E 10.74 328.04S 4865.06E S 77.60 E 12.67 332.93S 4890.27E S 76.00 E 8.40 338.86S 4915.50E 4678.94 4702.06 4725.81 4751.29 4777.12 10600.55 8743.81 8675.31 10631.70 8758.24 8689.74 10663.19 8771.60 8703.10 10694.25 8783.44 8714.94 10724.79 8793.81 8725.31 61 12 63 35 66 11 69 0 71 18 S 74.80 E 9.01 345.64S 4941.52E S 73.70 E 8.32 353.13S 4968.09E S 72.60 E 8.84 361.40S 4995.38E S 72.40 E 9.03 370.03S 5022.76E S 70.90 E 8.83 379.08S 5050.02E 4803.95 4831.53 4860.04 4888.75 4917.47 10756.36 8803.22 8734.72 10785.38 8810.54 8742.04 10817.40 8816.70 8748.20 10849.00 8821.23 8752.73 10879.23 8825.18 8756.68 74 0 76 48 81 0 82 30 82 30 S 71.70 E 8.89 S 72.60 E 10.10 S 73.60 E 13.47 S 73.90 E 4.84 S 74.70 E 2.62 388.74S 5078.56E 4947.60 397.34S 5105.29E 4975.68 406.47S 5135.35E 5007.09 415.22S 5165.37E 5038.34 423.33S 5194.22E 5068.29 'RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / B- 02A 50029200601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 DATE OF SURVEY: 072696 MWD SURVEY JOB NUMBER: AK-MW-60088 KELLY BUSHING ELEV. = 68.50 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 10969.92 8839.29 8770.79 79 35 S 74.20 E 3. 11062.76 8856.13 8787.63 79 30 S 75.70 E 1. 11156.40 8872.14 8803.64 80 48 S 74.00 E 2. 11250.28 8887.72 8819.22 80 5 S 72.80 E 1. 11343.79 8903.55 8835.05 80 24 S 73.00 E . 24 447.35S 5280.52E 59 471.05S 5368.68E 26 495.16S 5457.72E 46 521.61S 5546.43E 38 548.71S 5634.52E 5157.77 5248.93 5341.05 5433.59 5525.74 11437.72 8919.62 8851.12 79 54 S 72.30 E . 11526.57 8933.37 8864.87 82 18 S 71.30 E 2. 11619.11 8945.61 8877.11 82 30 S 73.60 E 2. 11712.89 8958.50 8890.00 81 41 S 73.10 E 1. 11806.24 8972.78 8904.28 80 41 S 71.80 E 1. 91 576.30S 5722.85E 92 603.72S 5806.23E 47 631.37S 5893.67E 00 657.99S 5982.66E 74 685.80S 6070.61E 5618.27 5706.04 5797.75 5890.60 5982.84 11897.04 8987.92 8919.42 80 5 S 72.00 E .70 713 11989.85 9003.80 8935.30 80 11 S 71.20 E .86 742 12082.44 9019.00 8950.50 80 54 S 71.90 E 1.06 771 12145.85 9030.61 8962.11 78 0 S 71.90 E 4.57 790 12177.61 9038.15 8969.65 74 30 S 73.40 E 11.94 799 .61S 6155.71E 6072.37 .48S 6242.47E 6163.81 .38S 6329.11E 6255.13 .74S 6388.35E 6317.47 .95S 6417.79E 6348.31 12208.89 9047.51 8979.01 70 41 S 74.40 E 12.53 808 12238.30 9058.02 8989.52 67 24 S 75.00 E 11.38 815 12283.00 9075.20 9006.70 67 24 S 75.00 E .00 826 .22S 6446.46E 6378.13 .47S 6472.95E 6405.56 .15S 6512.81E 6446.77 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6565.00 FEET AT SOUTH 82 DEG. 46 MIN. EAST AT MD = 12283 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 108.12 DEG. TIE-IN SURVEY AT 5,650' MD WINDOW POINT AT 5,663' MD PROJECTED SURVEY AT 12,283' MD ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU / B- 02A 50029200601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 DATE OF SURVEY: 072696 JOB NUMBER: AK-MW-60088 KELLY BUSHING ELEV. = 68.50 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5650.00 5185.90 5117.40 300.44 S 1510.47 E 6650.00 5906.48 5837.98 311.31 S 2201.14 E 7650.00 6637.49 6568.99 309.93 S 2882.93 E 8650.00 7357.39 7288.89 310.34 S 3576.85 E 9650.00 8085.44 8016.94 312.84 S 4262.13 E 464.10 743.52 279.42 1012.51 268.99 1292.61 280.10 1564.56 271.95 10650.00 8766.16 8697.66 357.85 S 4983.89 E 11650.00 8949.64 8881.14 640.02 S 5923.05 E 12283.00 9075.20 9006.70 826.15 S 6512.81 E 1883.84 319.28 2700.36 816.53 3207.80 507.44 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. qRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / B- 02A 50029200601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 DATE OF SURVEY: 072696 JOB NUMBER: AK-MW-60088 KELLY BUSHING ELEV. = 68.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5650.00 5185.90 5117.40 5757.51 5268.50 5200.00 5894.41 5368.50 5300.00 6034.79 5468.50 5400.00 300.44 S 1510.47 E 314.47 S 1577.75 E 320.63 S 1670.99 E 323.11 S 1769.45 E 464.10 489.01 24.91 525.91 36.91 566.29 40.38 6177.45 5568.50 5500.00 6318.74 5668.50 5600.00 6457.72 5768.50 5700.00 6596.85 5868.50 5800.00 6736.76 5968.50 5900.00 320.50 S 1871.15 E 316.04 S 1970.84 E 311.80 S 2067.26 E 310.99 S 2163.96 E 311.79 S 2261.82 E 608.95 42.66 650.24 41.29 689.22 38.98 728.35 39.13 768.26 39.91 6877.14 6068.50 6000.00 7016.08 6168.50 6100.00 7155.25 6268.50 6200.00 7292.51 6368.50 6300.00 7423.94 6468.50 6400.00 311.58 S 2360.33 E 311.12 S 2456.79 E 312.52 S 2553.56 E 312.94 S 2647.53 E 311.91 S 2732.80 E 808.64 40.37 847.58 38.94 886.75 39.17 924.01 37.26 955.44 31.42 7557.14 6568.50 6500.00 7692.06 6668.50 6600.00 7829.08 6768.50 6700.00 7968.48 6868.50 6800.00 8109.06 6968.50 6900.00 310.88 S 2820.78 E 309.73 S 2911.34 E 308.47 S 3005.00 E 307.43 S 3102.11 E 307.02 S 3200.91 E 988.64 33.20 1023.56 34.92 1060.58 37.02 1099.98 39.40 1140.56 40.58 8247.09 7068.50 7000.00 8385.43 7168.50 7100.00 8525.19 7268.50 7200.00 8665.71 7368.50 7300.00 8805.26 7468.50 7400.00 307.18 S 3296.05 E 307.63 S 3391.64 E 309.40 S 3489.25 E 310.49 S 3587.96 E 311.47 S 3685.27 E 1178.59 38.03 1216.93 38.34 1256.69 39.76 1297.21 40.52 1336.76 39.55 8941.23 7568.50 7500.00 9076.48 7668.50 7600.00 9212.95 7768.50 7700.00 9350.79 7868.50 7800.00 9488.23 7968.50 7900.00 311.06 S 3777.40 E 311.84 S 3868.45 E 312.85 S 3961.30 E 315.08 S 4056.14 E 315.49 S 4150.40 E 1372.73 35.97 1407.98 35.25 1444.45 36.47 1482.29 37.84 1519.73 37.44 9626.40 8068.50 8000.00 9766.29 8168.50 8100.00 9906.96 8268.50 8200.00 10044.82 8368.50 8300.00 10182.15 8468.50 8400.00 313.18 S 4245.72 E 311.39 S 4343.52 E 312.52 S 4442.43 E 313.55 S 4537.32 E 314.88 S 4631.43 E 1557.90 38.17 1597.79 39.89 1638.46 40.67 1676.32 37.86 1713.65 37.33 10320.99 8568.50 8500.00 317.42 S 4727.71 E 1752.49 38.84 ?~qRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / B- 02A 50029200601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 DATE OF SURVEY: 072696 JOB NUMBER: AK-MW-60088 KELLY BUSHING ELEV. = 68.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10467.07 8668.50 8600.00 323.73 S 4833.94 E 1798.57 46.08 10655.73 8768.50 8700.00 359.40 S 4988.89 E 1887.23 88.66 11133.62 8868.50 8800.00 488.96 S 5436.10 E 2265.12 377.88 11779.78 8968.50 8900.00 677.64 S 6045.81 E 2811.28 546.17 12265.57 9068.50 9000.00 821.99 S 6497.27 E 3197.07 385.78 12283.00 9075.20 9006.70 826.15 S 6512.81 E 3207.80 10.73 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS S~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU / B-02A 500292006601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 PAGE DATE OF SURVEY: 071896 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60094 KELLY BUSHING ELEV. = 68.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5650.00 5185.90 5117.40 5846.35 5333.80 5265.30 5938.34 5399.85 5331.35 6029.33 5464.49 5395.99 6122.62 5530.27 5461.77 38 47 43 46 44 25 45 2 45 17 S 74.66 E .00 300.44S 1510.47E N 89.59 E 5.86 316.28S 1638.14E S 87.75 E 2.13 317.31S 1702.13E N 88.74 E 2.79 317.85S 1766.14E N 87.72 E .82 315.80S 1832.26E 1529.00 1655.26 1716.40 1777.40 1839.60 6216.25 5595.52 5527.02 6310.54 5662.26 5593.76 6404.09 5730.01 5661.51 6496.67 5796.71 5728.21 6589.30 5863.27 5794.77 46 20 43 31 43 40 44 7 43 59 N 86.90 E 1.29 312.64S 1899.32E N 85.88 E 3.09 308.46S 1965.78E N 86.47 E .47 304.16S 2030.15E N 86.01 E .60 299.95S 2094.21E N 88.64 E 1.98 296.94S 2158.55E 1902.36 1964.23 2024.07 2083.64 2143.85 6683.43 5930.86 5862.36 6777.54 5998.20 5929.70 6870.00 6063.99 5995.49 6963.18 6130.80 6062.30 7057.43 6198.94 6130.44 44 13 44 24 44 52 43 30 43 53 N 88.95 E .33 295.56S 2224.05E N 88.98 E .19 294.37S 2289.78E N 89.18 E .54 293.33S 2354.73E N 89.11 E 1.47 292.36S 2419.68E N 89.18 E .41 291.39S 2484.78E 2205.67 2267.77 2329.18 2390.60 2452.18 7149.56 6265.05 6196.55 7241.41 6331.96 6263.46 7331.61 6399.84 6331.34 7425.67 6471.33 6402.83 7518.04 6541.01 6472.51 44 23 42 3 40 17 40 45 41 18 N 89.41 E .58 290.60S 2548.94E S 89.52 E 2.67 290..53S 2611.84E N 89.03 E 2.22 290.29S 2671.21E N 89.97 E .81 289.76S 2732.33E S 89.94 E .60 289.77S 2792.97E 2512.91 2572.66 2629.02 2686.94 2744.58 7610.23 6609.95 6541.45 7704.52 6679.67 6611.17 7798.86 6748.62 6680.12 7893.02 6816.69 6748.19 7986.27 6883.35 6814.85 41 53 42 43 43 21 44 2 44 41 N 89.74 E .67 289.67S 2854.18E S 89.55 E 1.02 289.77S 2917.65E S 89.73 E .69 290.18S 2982.04E S 89.87 E .73 290.40S 3047.09E S 89.98 E .70 290.48S 3112.29E 2802.72 2863.07 2924.40 2986.29 3048.29 8079.60 6949.46 6880.96 8171.25 7015.33 6946.83 8264.81 7083.58 7015.08 8357.22 7150.53 7082.03 8450.91 7217.89 7149.39 45 6 42 58 43 20 43 48 44 14 S 89.37 E .64 290.86S 3178.17E N 89.94 E 2.38 291.18S 3241.87E S 89.15 E .76 291.63S 3305.86E S 89.18 E .52 292.56S 3369.55E S 89.06 E .47 293.56S 3434.66E 3111.01 3171.66 3232.62 3293.44 3355.62 8544.35 7284.70 7216.20 8638.41 7351.69 7283.19 8732.53 7418.38 7349.88 8826.40 7486.12 7417.62 8920.65 7555.75 7487.25 44 28 44 41 45 2 42 33 42 10 S 88.64 E .41 294.87S 3499.98E S 88.60 E .24 296.46S 3565.99E S 88.69 E .38 298.03S 3632.37E S 89.50 E 2.72 299.07S 3697.32E S 89.39 E .41 299.68S 3760.84E 3418.11 3481.34 3544.92 3606.98 3667.53 ?~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU / B-02A 500292006601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 PAGE DATE OF SURVEY: 071896 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60094 KELLY BUSHING ELEV. = 68.50 FT. OPEtLATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9011.54 7623.05 7554.55 42 16 S 89.13 E .22 300.46S 3821.92E 9104.12 7691.37 7622.87 42 36 S 89.48 E .43 301.22S 3884.39E 9194.63 7757.76 7689.26 43 2 S 88.49 E .88 302.31S 3945.90E 9254.00 7801.03 7732.53 43 22 S 88.50 E .56 303.38S 3986.53E 9289.49 7826.80 7758.30 43 32 S 88.32 E .58 304.06S 4010.93E 3725.83 3785.44 3844.23 3883.18 3906.58 9383.80 7894.94 7826.44 43 56 S 87.90 E .53 306.21S 4076.09E 9478.15 7963.49 7894.99 42 52 N 89.67 E 2.11 307.23S 4140.89E 9571.48 8031.53 7963.03 43 30 N 89.15 E .79 306.56S 4204.77E 9664.34 8098.48 8029.98 44 12 N 88.69 E .82 305.35S 4269.09E 9757.65 8165.14 8096.64 44 36 N 89.29 E .62 304.20S 4334.38E 3969.18 4031.09 4091.58 4152.34 4214.03 9848.60 8229.50 8161.00 45 17 N 89.94 E .90 303.77S 4398.63E 9941.54 8296.11 8227.61 43 7 N 89.96 E 2.33 303.71S 4463.43E 10035.75 8364.86 8296.36 43 7 S 89.57 E .35 303.93S 4527.84E 10091.29 8405.44 8336.94 43 0 S 89.20 E .50 304.34S 4565.76E 10129.29 8433.21 8364.71 43 6 S 88.92 E .57 304.77S 4591.70E 4274.97 4336.53 4397.81 4433.98 4458.77 10223.71 8501.78 8433.28 43 45 S 87.74 E 1.10 306.66S 4656.58E 10272.00 8536.60 8468.10 43 57 S 87.97 E .55 307.92S 4690.01E 10385.00 8617.94 8549.44 43 57 S 87.97 E .00 310.69S 4768.40E 4521.02 4553.18 4628.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4778.51 FEET AT SOUTH 86 DEG. 16 MIN. EAST AT MD = 10385 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 108.12 DEG. TIE-IN SURVEY AT 5,650' MD PROJECTED SURVEY AT 10,385' MD ?~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / B-02A 500292006601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 DATE OF SURVEY: 071896 JOB NUMBER: AK-EI-60094 KELLY BUSHING ELEV. = 68.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5650.00 5185.90 5117.40 6650.00 5906.90 5838.40 7650.00 6639.55 6571.05 8650.00 7359.92 7291.42 9650.00 8088.21 8019.71 300.44 S 295.99 S 289.55 S 296.66 S 305.57 S 1510.47 E 464.10 2200.74 E 743.10 279.00 2880.73 E 1010.45 267.35 3574.14 E 1290.08 279.63 4259.10 E 1561.79 271.72 10385.00 8617.94 8549.44 310.69 S 4768.40 E 1767.06 205.27 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ?~ERRY-SUN DRILLING SERVICES · ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU / B-02A 500292006601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 PAGE DATE OF SURVEY: 071896 JOB NUMBER: AK-EI-60094 KELLY BUSHING ELEV. = 68.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATE S NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5650.00 5185.90 5117.40 5757.81 5268.50 5200.00 5894.45 5368.50 5300.00 6035.00 5468.50 5400.00 300.44 S 1510.47 E 313.25 S 1578.46 E 316.16 S 1671.45 E 317.76 S 1770.15 E 464.10 489.31 25.21 525.95 36.65 566.50 40.55 6177.10 5568.50 5500.00 6319.14 5668.50 5600.00 6457.36 5768.50 5700.00 6596.57 5868.50 5800.00 6735.97 5968.50 5900.00 314.17 S 1871.04 E 308.03 S 1971.69 E 301.85 S 2066.91 E 296.82 S 2163.59 E 294.89 S 2260.70 E 608.60 42.10 650.64 42.04 688.86 38.22 728.07 39.20 767.47 39.40 6876.36 6068.50 6000.00 7015.20 6168.50 6100.00 7154.39 6268.50 6200.00 7290.52 6368.50 6300.00 7421.93 6468.50 6400.00 293.26 S 2359.22 E 291.81 S 2455.51 E 290.57 S 2552.32 E 290.74 S 2644.64 E 289.76 S 2729.89 E 807.86 40.40 846.70 38.83 885.89 39.20 922.02 36.13 953.43 31.41 7554.65 6568.50 6500.00 7689.31 6668.50 6600.00 7826.21 6768.50 6700.00 7965.38 6868.50 6800.00 8106.57 6968.50 6900.00 289.79 S 2817.15 E 289.69 S 2907.33 E 290.26 S 3000.81 E 290.48 S 3097.60 E 291.07 S 3197.28 E 986.15 32.72 1020.81 34.66 1057.71 36.90 1096.88 39.17 1138.07 41.19 8244.08 7068.50 7000.00 8382.13 7168.50 '7100.00 8521.65 7268.50 7200.00 8662.07 7368.50 7300.00 8802.48 7468.50 7400.00 291.42 S 3291.64 E 292.80 S 3386.80 E 294.49 S 3484.08 E 296.86 S 3582.62 E 298.93 S 3681.15 E 1175.58 37.51 1213 . 63 38 . 05 1253.15 39.52 1293.57 40.42 1333.98 40.42 8937.86 7568.50 7500.00 9073.05 7668.50 7600.00 9209.33 7768.50 7700.00 9347.09 7868.50 7800.00 9484.99 7968.50 7900.00 299.80 S 3772.39 E 301.03 S 3863.36 E 302.58 S 3955.93 E 305.28 S 4050.64 E 307.20 S 4145.55 E 1369.36 35.37 1404.55 35.19 1440.83 36.28 1478.59 37.76 1516.49 37.90 9622.54 8068.50 8000.00 9762.37 8168.50 8100.00 9903.65 8268.50 8200.00 10040.73 8368.50 8300.00 10177.69 8468.50 8400.00 305.99 S 4239.98 E 304.16 S 4337.69 E 303.73 S 4437.49 E 303.96 S 4531.24 E 305.46 S 4624.81 E 1554.04 37.55 1593.87 39.83 1635.15 41.29 1672.23 37.08 1709.19 36.95 10316.32 8568.50 8500.00 309.00 S 4720.76 E 1747.82 38.63 ~ERRY-SUNDRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU / B-02A 500292006601 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/96 PAGE 5 DATE OF SURVEY: 071896 JOB NUMBER: AK-EI-60094 KELLY BUSHING ELEV. = 68.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10385.00 8617.94 8549.44 310.69 S 4768.40 E 1767.06 19.24 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS gyro/data B.P. EXPLORATION WELL NO: B-02A B-PAD, NORTH SLOPE, ALASKA Gyro Multishot Survey In 10 3/4,9 5/8 Casing Survey date: 02-JULY, 1996 Job number: AK0796C355 SR355.DOC gyro/data Gyrodata Incorporated RO. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 July 09, 1996 B.P. Exploraton (Alaska) Inc. Petrotechnical Data Center 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re: B Pad, Well No. B-02A, North Slope, AK Enclosed please find one (1) original and six (6) copies and one (1) disk of the completed survey of Well No: B-02A We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the furore. Sincerely Robert J. Shoup Operations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation gym/data CONTENTS JOB NUMBER :AK0796C355 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR355.DOC g.vra I 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR355.DOC gyro/data DISCUSSION JOB NUMBER' AK0796C355 Tool 705 was run in well #B-02A on ATLAS 15/32" Wireline inside 10 3/4" & 9 5/8" casing, survey was run without problems. SR355.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER' AK0796C355 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. JACK MAY OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR355.DOC gyro/data 2. SURVEY DETAILS SR355.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0796C355 CLIENT: B.P. EXPLORATION RIG: DOYAN 16 LOCATION: B-PAD NORTH SLOPE,ALASKA WELL: B-02A LATITUDE: 70.16 LONGITUDE: 148.5 W SURVEY DATE: 02-J U LY, 1996 SURVEY TYPE : MULTISHOT IN 10 3/4-9 5/8"CASING DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 68.68FT. 5663 FT. SURVEY TIED ONTO: NA SURVEY INTERVAL: 100' FROM 0- 3000' 50' FROM 3000'- 5650' UTM CO-ORDINATES: TARGET DIRECTION: 108.12 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: JACK MAY SR355.DOC .gyro/data 3. OUTRUN SURVEY LISTING A Gyrodat a D i re c t iona i Survey for PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355 Run Date: 2-Jul-96 13:00:00 Surveyor: JACK MAY Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.160000 deg. N Sub-sea Correction from Vertical Reference: 68.68 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 108.120 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodat a D i r e c t iona i Survey PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355 MEASURED I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -68.7 0.00 0.0 0.0 (0-5663ft.) A GYRO MULTISHOT SURVEY IN 10 3/4"& 9 5/8" CASING ALL MEASURED DEPTHS REFERENCED TO DOYAN 16 RKB ELEV.OF 68.68' Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .30 267.77 100.0 -.2 31.3 .30 200.0 .16 108.43 200.0 -.4 131.3 .46 300.0 .06 258.92 300.0 -.3 231.3 .22 400.0 .04 207.24 400.0 -.3 331.3 .05 500.0 .08 157.02 500.0 -.3 431.3 .06 600.0 .03 208.18 600.0 -.2 531.3 .07 700.0 .05 55.67 700.0 -.2 631.3 .08 800.0 .10 126.50 800.0 -.1 731.3 .10 900.0 .07 95.42 900.0 .0 831.3 .05 1000.0 .05 5.29 1000.0 .1 931.3 .09 1100 · 0 . 04 315 . 92 1100 · 0 . 0 1031 . 3 . 04 1200 . 0 · 08 321 . 96 1200 · 0 - · 0 1131 · 3 . 04 1300 . 0 · 05 51 . 06 1300 · 0 - . 1 1231.3 . 09 1400 . 0 · 06 253 . 65 1400 . 0 - . 1 1331.3 · 11 1500 . 0 . 06 37 . 70 1500 · 0 - . 1 1431 . 3 . 12 1600.0 .04 218.87 1600.0 -.1 1531.3 .10 1700.0 .05 122.83 1700.0 -.1 1631.3 .06 1800.0 .04 30.21 1800.0 -.0 1731.3 .07 1900.0 .02 90.74 1900.0 -.0 1831.3 .04 2000.0 .05 280.67 2000.0 -.0 1931.3 .07 .3 267.8 .4 260.8 .3 249.5 .4 247.6 .5 235.9 .5 226.5 .5. 224.7 .4 212.4 .4 193.5 .4 185.1 .3 189.6 .3 205.3 .2 215.9 .2 221.6 .2 230.2 .2 231.7 .2 219.2 .2 207.7 .1 200.8 .1 213.1 .01 S .27W .06 S .40 W .12 S .32 W .16 S .39 W .26 S .38 W .35 S .37 W .35 S .34 W .38 S .24 W .44 S .10 W .40 S .04 W .33 S .06 W .25 S .12 W .17 S .13 W .16 S .14 W .14 S .16 W .12 S .15 W .17 S .14 W .15 S .08 W .12 S .05 W .11 S .07 W A Gyroda t a D i r e c t i ona i Survey PRUDHOE BAY DRILLING NELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA 3ob Number: AK0796C355 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATE S feet 2100.0 .09 137.67 2100.0 2200.0 .02 255.68 2200.0 2300.0 .04 56.23 2300.0 2400.0 .53 99.18 2400.0 2500.0 3.29 107.37 2499.9 -.0 .0 .0 .5 3.9 2031.3 2131.3 2231.3 2331.3 2431.3 .13 .2 202.3 .10 .2 188.5 .06 .2 185.8 .50 .5 118.9 2.76 3.9 108.0 .16 S .07 W .22 S .03 W .20 S .02 W .26 S .47 E 1.19 S 3.66 E 2600.0 5.83 104.26 2599.6 2700.0 9.04 98.32 2698.8 2800.0 11.46 96.60 2797.2 2900.0 13.56 97.73 2894.8 3000.0 15.34 97.34. 2991.6 11.8 24.6 42.1 63.3 87.9 2530.9 2.55 11.8 106.2' 2630.1 3.30 24.7 103.3 2728.5 2.44 42.4 100.8 2826.1 2.11 64.0 99.6 2922.9 1.79 89.0 99.0 3.30 S 11.32 E 5.68 S 24.02 E 7.96 S 41.66 E 10.68 S 63.14 E 13.95 S 87.88 E 3050.0 16.54 98.22 3039.7 3100.0 17.88 98.99 3087.4 3150.0 19.07 99.39 3134.9 3200.0 20.49 100.17 3181.9 3250.0 21.97 100.25 3228.5 101.4 116.0 131.6 148.4 166.3 2971.0 2.45 102.7 98.9 3018.8 2.71 117.5 98.8 3066.2 2.40 133.4 98.9 3113.2 2.88 150.3 99.0 3159.8 2.97 168.4 99.1 15.81 S 101.48 E 18.03 S 116.11 E 20.56 S 131.76 E 23.44 S 148.43 E 26.65 S 166.25 E 3300.0 23.23 100.19 3274.7 3350.0 24.09 100.23 3320.5 3400.0 25.01 100.16 3366.0 3450.0 25.97 100.07 3411.1 3500.0 27.21 100.22 3455.8 185.3 205.2 225.8 247.1 269.2 3206.0 2.52 187.6 99.2 3251.8 1.73 207.6 99.3 3297.3 1.85 228.4 99.4 3342.4 1.91 249.9 99.5 3387.1 2.48 272.3 99.5 30.06 S 185.15 E 33.61 S 204.90 E 37.29 S 225.35 E 41.07 S 246.54 E 45.02 S 268.57 E 3550.0 28.47 100.01 3500.0 3600.0 29.00 99.94 3543.9 3650.0 29.16 100.05 3587.5 3700.0 29.17 99.89 3631.2 3750.0 29.13 100.00 3674.9 292.4 316.2 340.2 364.3 388.4 3431.3 3475.2 3518.9 3562.5 3606.2 2.52 295.7 99.6 1.07 319.7 99.6 .33 344.0 99.6 .16 368.4 99.6 .13 392.7 99.7 49.11 S 291.55 E 53.28 S 315.23 E 57.50 S 339.16 E 61.71 S 363.15 E 65.92 S 387.14 E A Gyro da t a D i r e c t i ona i Survey PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355 Page MEASURED I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3800.0 29.08 100.18 3718~6 412.5 3850.0 29.58 100.41 3762.2 436.8 3900.0 30.69 100.44 3805.4 461.7 3950.0 31.84 100.19 3848.1 487.4 4000.0 33.55 100.15 3890.2 514.1 3649.9 3693.5 3736.7 3779.5 3821.5 .21 417.0 99.7 1.01 441.5 99.7 2.23 466.6 99.8 2.30 492.6 99.8 3.43 519.6 99.8 70.18 S 411.09 E 74.56 S 435.19 E 79.10 S 459.87 E 83.75 S 485.40 E 88.51 S 511.98 E 4050.0 35.20 99.79 3931.5 542.1 4100.0 36.58 99.71 3972.0 571.1 4150.0 37.44 99.75 4011.9 600.8 4200.0 37.62 99.85 4051.6 631.0 4250.0 37.83 100.11 4091.1 661.3 3862.8 3903 .3 3943.2 3982.9 4022.4 .33 547.8 99.8 .75 577.1 99.8 .72 607.2 99.8 .39 637.7 99.8 .52 668.3 99.8 93.40 S 539.79 E 98.36 S 568.67 E 103.45 S 598.34 E 108.63 S 628.35 E 113.93 S 658.48 E 4300.0 37.95 100.05 4130.6 691.7 4350.0 38.13 100.29 4170.0 722.2 4400.0 38.03 100.32 4209.3 752.7 4450.0 38.12 100.76 4248.7 783.3 4500.0 38.25 100.99 4288.0 814.0 4061.9 4101.3 4140.6 4180.0 4219.3 .26 699.0 99.8 .46 729.8 99.8 .19 760.6 99.9 .57 791.4 99.9 .38 822.4 99.9 119.30 S 688.71 E 124.74 S 719.04 E 130.26 S 749.38 E 135.90 S 779.69 E 141.73 S 810.05 E 4550.0 38.19 101.23 4327.3 844.7 4600.0 38.22 101.50 4366.5 875.4 4650.0 38.19 101.14 4405.8 906.1 4700.0 38.10 101.00 4445.2 936.7 4750.0 38.16 101.29 4484.5 967.4 4258.6 4297.9 4337.2 4376.5 4415.8 · 31 853.3 100.0 .35 884.2 100.0 .45 915.1 100.1 .24 946.0 100.1 .37 976.9 100.1 147.69 S 840.40 E 153.78 S 870.72 E 159.85 S 901.04 E 165.78 S 931.34 E 171.75 S 961.63 E 4800.0 38.12 101.09 4523.8 998.0 4850.0 38.30 101.23 4563.1 1028.7 4900.0 38.04 101.51 4602.4 1059.4 4950.0 38.36 101.71 4641.7 1090.1 5000.0 38.38 102.15 4680.9 1121.0 4455.1 4494.4 4533.7 4573.0 4612.2 .26 1007.7 100.2 .41 1038.6 100.2 .62 1069.5 100.2 .69 1100.5 100.3 .55 1131.5 100.3 177.74 S 183.73 S 189.82 S 196.05 S 202.46 S 991.93 E 1022.27 E 1052.56 E 1082.85 E 1113.22 E A Gyroda t a D i r e c t i ona i Survey PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355 Page MEASURED I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY.DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5050.0' 38.71 102.37 4720.0 1152.0 5100.0 39.16 102.87 4758.9 1183.3 5150.0 39.18 103.25 4797.7 1214.7 5200.0 39.11 103.25 4836.4 1246.2 5250.0 39.32 103.61 4875.2 1277.7 4651.3 .72 1162.6 100.4 4690.2 1.09 1194.0 100.4 4729.0 .47 1225.6 100.5 4767.8 .13 1257.1 100.6 4806.5 .61 1288.7 100.6 209.08 S 1143.67 E 215.94 S 1174.33 E 223.08 S 1205.09 E 230.31 S 1235.82 E 237.65 S 1266.56 E 5300.0 39.00 103.74 4914.0 1309.1 5350.0 39.30 103.65 4952.7 1340.6 5400.0 39.11 103.95 4991.5 1372.1 5450.0 38.81 104.64 5030.4 1403.5 5500.0 38.78 104.93 5069.3 1434.8 4845.3 .66 1320.2 100.7 4884.1 .62 1351.7 100.8 4922.8 .54 1383.3 100.8 4961.7 1.05 1414.7 100.9 5000.6 .36 1445.9 101.0 245.12 S 1297.24 E 252.59 S 1327.91 E 260.12 S 1358.60 E 267.88 S 1389.07 E 275.88 S 1419.36 E 5550.0 39.10 105.02 5108.2 1466.1 5600.0 39.07 105.11 5147.0 1497.6 5650.0 38.79 105.34 5185.9 1529.0 5663.0 38.66 106.93 5196.1 1537.1 5039.5 .65 1477.3 101.1 5078.3 .12 1508.7 101.2 5117.2 .64 1540.1 101.2 5127.4 7.70 1548.2 101.3 284.00 S 292.19 S 300.44 S 302.70 S 1449.72 E 1480.16 E 1510.47 E 1518.28 E Final Station Closure: Distance: 1548.17 ft Az: 101.28 deg. A Gyroda t a D i re c t i ona i Survey for PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355SS Run Date: 2-Jul-96 13:00:00 Surveyor: JACK MAY Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.160000 deg. N Sub-sea Correction from Vertical Reference: 68.68 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction- 108.120 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodat a D i re c t iona i Survey PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355SS SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. -68.7 0.00 0.00 0.0 0.0 0.00 0.0 0.0 (0-5663ft.) A GYRO MULTISHOT SURVEY IN 10 3/4"& 9 5/8" CASING ALL MEASURED DEPTHS REFERENCED TO DOYAN 16 RKB ELEV.OF 68.68' HORIZONTAL COORDINATES feet 0.00 N 0.00 E Page 100.0 .21 158.33 168.7 -.3 .41 .4 263.0 200.0 .09 211.78 268.7 -.3 .29 .3 253.0 300.0 .05 223.42 368.7 -.3 .10 .4 248.2 400.0 .07 172.75 468.7 -.3 .06 .5 239.6 500.0 .05 192.15 568.7 -.3 .07 .5 229.4 600.0 .04 103.43 668.7 -.2 .07 .5 225.3 700.0 .08 104.31 768.7 -.1 .09 .4 216.3 800.0 .08 105.15 868.7 -.0 .07 .4 199.4 900.0 .06 33.52 968.7 .1 .08 .4 187.8 000.0 .04 331.38 1068.7 .1 .05 .3 188.2 100.0 .06 320.07 1168.7 -.0 .04 .3 200.4 200.0 .06 135.90 1268.7 -.1 .07 .2 212.6 300.0 .06 190.20 1368.7 -.1 .10 .2 219.8 400.0 .06 105.33 1468.7 -.1 .11 .2 227.5 500.0 .04 162.13 1568.7 -.1 .10 .2 231.3 600.0 .04 152.91 1668.7 -.1 .07 .2 223.2 700'.0 .05 59.22 1768.7 -.0 .07 .2 211.3 800.0 .03 71.78 1868.7 -.0 .05 .1 202.9 900.0 .04 221.19 1968.7 -.0 .06 .1 209.2 000.0 .07 182.45 2068.7 -.0 .11 .2 205.7 .05 S .36 W .10 S .35 W .15 S .37 W .23 S .38 W .32 S .37 W .35 S .35 W .37 S .27 W .42 S .15 W .41 S .06 W .35 S .05 W .28 S .10 W .20 S .12 W .17 S .14 W .14 S .16 W .12 S .15 W .15 S .14 W .16 S .10 W .13 S .06 W .12 S .06 W .15 S .07 W A Gyro da t a D i r e c t i ona i Survey PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL C O O R D I N A T.E S feet 2100.0 .04 218.72 2168.7 .0 2200.0 .04 118.70 2268.7 .0 2300.0 .38 85.73 2368.7 .4 2400.0 2.43 104.81 2468.7 2.8 2500.0 5.04 105.22 2568.7 9.3 .11 .2 192.8 .07 .2 186.6 .36 .5 139.9 .06 3.9 111.4 .62 11.8 106.8 .20 S .04 W .21 S .02 W .24 S .33 E .90 S 2.67 E 2.64 S 8.95 E 2600.0 8.06 100.12 2668.7 20.7 2700.0 10.76 97.10 2768.7 37.0 2800.0 12.99 97.43 2868.7 57.6 2900.0 14.92 97.44 .2968.7 82.0 3000.0 17.36 98.69 3068.7 110.2 3.07 24.7 104.2 2.69 42.4 101.5 2.20 64.0 99.9 1.87 89.0 99.2 2.61 117.5 98.8 4.96 S 20.17 E 7.30 S 36.55 E 9.95 S 57.40 E 13.17 S 82.02 E 17.16 S 110.37 E 3100.0 20.09 99.95 3168.7 143.6 3200.0 23.06 100.19 3268.7 182.8 3300.0 25.07 100.16 3368.7 227.1 3400.0 27.58 100.16 3468~.7 276.0 3500.0 29.09 100.00 3568.7 329.8 2.74 150.3 98.9 2.58 187.6 99.2 1.85 249.9 99.4 2.49 295.7 99.5 .65 344.0 99.6 22.63 S 143.74 E 29.61 S 182.70 E 37.52 S 226.63 E 46.21 S 275.27 E 55.67 S 328.83 E 3600.0 29.14 99.98 3668.7 385.0 3700.0 29.74 100.41 3768.7 440.5 3800.0 32.67 100.17 3868.7 500.4 3900.0 36.46 99.71 3968.7 568.7 4000.0 37.71 99.96 4068.7 644.1 .13 392.7 99.7 .20 466.6 99.7 .85 519.6 99.8 .80 577.1 99.8 .45 668.3 99.8 65.32 S 383.74 E 75.24 S 438.91 E 86.07 S 498.38 E 97.96 S 566.32 E 110.92 S 641.38 E 4100.0 38.12 100.28 4168.7 721.2 4200%0 38.19 100.88 4268.7 798.9 4300.0 38.21 101.48 4368.7 877.0 4400.0 38.14 101.17 4468.7 955.0 4500.0 38.27 101.27 4568.7 1033.1 .46 729.8 99.8 .47 822.4 99.9 .35 915.1 100.0 .32 976.9 100.1 .44 1069.5 100.2 124.57 S 718.05 E 138.87 S 795.14 E 154.11 S 872.36 E 169.35 S 949.45 E 184.59 S 1026.56 E A Gyrodat a D i r e c t iona i Survey PRUDHOE BAY DRILLING WELL: B-PAD B-02A, 10 3/4"-9 5/8" Location: DOYAN 16, NORTH SLOPE,ALASKA Job Number: AK0796C355SS SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH ~deg. / feet deg. 100 ft. H O R'I Z 0 N T A L C.O O R D I N A T E S feet 4600.0 38.38 102.01 4668.7 1111.4 4700.0 39.16 102.97 4768.7 1191.2 4800.0 39.28 103.55 4868.7 1272.4 4900.0 39.22 103.77 4968.7 1353.6 5000.0 38.78 104.92 5068.7 1434.3 .59 .94 .53 .59 .38 1131.5 100.3 1225.6 100.4 1288.7 100.6 1383.3 100.8 1445.9 101.0 200.46 S 1103.75 E 217.74 S 1182.09 E 236.42 S 1261.40 E 255.69 S 1340.55 E 275.74 S 1418.86 E 5100.0 38.91 105.23 5168.7 1515.1 5127.4 38.66 106.93 5196.1 1537.1 .40 1540.1 101.2 7.70 1548.2 101.3 296.78 S 1497.04 E 302.70 S 1518.29 E Final Station Closure: Distance: 1548.17 ft Az: 101.28 deg. Page gyro/data 4. QUALITY CONTROL SR355.DOC gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0796C355 TOOL NUMBER: 7O5 MAXIMUM GYRO TEMPERATURE: 77.29 C MAXIMUM AMBIENT TEMPERATURE: 39.9 C MAXIMUM INCLINATION: 39.30 AVERAGE AZIMUTH: 101.28 WIRELINE REZERO VALUE' 3.1' REZERO ERROR/K: .5535714 CALIBRATION USED FOR FIELD SURVEY: 1522 CALIBRATION USED FOR FINAL SURVEY: 1522 PRE JOB MASS BALANCE OFFSET CHECK: .3 POST JOB MASS BALANCE OFFSET CHECK]: CONDITION OF SHOCK WATCHES 1.13 USED -0.0 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 5663 38.66 106.93 5196.1 -302.70 1518.28 FINAL SURVEY 5663 38.66 106.93 5196.1 -302.70 1518.28 SR355.DOC gyro/data' FUNCTION TEST JOB NUMBER: AK0796C355 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft ' 1 2 3 4 5 5550 39.10 39.10 39.10 39.10 39.10 AZIMUTH M.D. ft 1 2 3 4 5 5550 105.02 105.0 105.1 105.2 105.3 SR355.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR355.DOC gyro/data EQUIPMENT REPORT JOB NUMBER' AK0796C355 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 705 GYRO SECTION A0092 DATA SECTION C0011 POWER SECTION C0042 BACKUP TOOL No. 751 GYRO SECTION AD106 DATA S ECTI ON C0025 POWER SECTION C0026 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0222 A0107 A0079 A0035 A0122 A0074 A0029 A0035 WIRELINE COMPANY' CABLE SIZE ' ATLAS WIRELINE 15/32" RUNNING GEAR 2,5" SYSTEM TOTAL LENGTH OF TOOL' MAXIMUM O.D.' TOTAL WEIGHT OF TOOL ' 23.5 FEET 2.5 INCHES 210 POUNDS SR355.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0796C355 07/02/96 01:00 01:20 02:00 02:30 11:15 12:00 12:40 13:30 13:50 14:20 15:30 15:20 16:30 17:00 TRANS TO LOCATION ARRIVE AT LOCATION MU TOOL TOOL WORKING, STANDBY PU TOOL, MU PUMPIN SUB RIH. 3000' START INRUN CONTINUOUS. 5650'END DATAFILE AND PROCESS.DATA LOOKS GOOD BUT GYRODATA IS UP TO 30 DEG. OFF THE PREVIOUS GYRO SURVEY RUN IN 1970 BY SPERRY SUN. 5650' START OUTRUN CONTINUOUS 3000' END OUTRUN DATAFILE, PROCESS DATA SURVEY OUT OF HOLE, (3000' TO 0') LAID DOWN THE TOOL,AND CHECKED ON SURFACE. TOOL NOT WORKING PROPERLY. DECIDED TO RETURN TO ATLAS AND TRY TO STARTUP THE GYRO. IF WE COULD, WE FELT THIS WS ALL THAT WAS NECESSARY TO Q.C. THE SURVEY. ONCE WE RETURNED TO ATLAS AND FOUND THE GYRO WOULD NOT RESPOND TO THE STARTUP PROCEDURES, WE FELT THERE WAS NO CHOICE OTHER THAN TO CALL THE SURVEY A MISRUN. NOTIFIED THE CO. MAN OF THE SITUATION AND HE DECIDED TO RERUN AT A LATER TIME. SR355.DOC gyro/data 07/03/96 08:00 ARRIVE AT LOCATION 08:20 BUILD TOOL ,CHECK OUT EQUIPMENT, CHECKS O.K. 08:40 STAND BY FOR ATLAS TO FINISH CBT LOG. 11:00 P.U. TOOL AND R.I.H. 11:15 START SURVEYING AT 500' INTERVALS TO T.D. BY THIS POINT WE NEW THE PREVIOUS SURVEY WAS VALID BY COMPARING THE NEW DATA WITH THE OLD. 13:00 FINISHED OUTRUN G.C. SURVEY 13:10 P.O.O.H AND LAID DOWN THE TOOL 13:30 RETURNED TO ATLAS TO Q.C. THE GYRO AND PROCESS THE SURVEY. 14:50 POST JOB GYRO CALIBRATION FROM TOOL STAND ON THE SLOPE PROVED TO BE GOOD. 15:30 PROCESSED THE GYRO COMPASS SURVEY AND IT MATCHED THE SURVEY FROM THE FIRST RUN ON 07/02/96. 16:30 RETURNED TO THE DRILL SITE AND TURNED IN THE FINAL SURVEY WITCH WAS THE CONTINUOUS RUN FROM THE PREVIOUS DAY. 17:30 RETURNED TO ANCHORAGE. SR355.DOC GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10505 Company: Field: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 10/22/96 Well Job # Log Description Date BL RF Sepia LIS Tape B,:O 1 PRODUCTION PROFILE 9 61 0 0 2 I 1 i!i~.~2A PERFORATING RECORD 960928 I 1 C- 12 INFLATABLE BRIDGE PLUG 9 61 00 4 I 1 C- 12 INFLATABLE BRIDGE PLUG 9 61 01 0 I 1 C- 32 PERFORATING RECORD 9 61 00 5 1 1 C-42 TUBING PUNCH 9 60 92 9 I 1 ~ F- 16 LEAK DETECTION LOG 9 61 01 I I 1 ,, -- F-16 BAKER WHIPSTOCK SET.REC. 9 61 01 2 1 1 G-12A TUBING PUNCH 9 60 93 0 I 1 G-12A TUBING PUNCH 9 61 001 I 1 H- 19 PERFORATING RECORD 9 61 00 7 1 1 J-08 . PERFORATING RECORD 9 61 0 01 I 1 J-08 TUBING PUNCH 961 01 3 I 1 W-03 PERF. RECORD 9 61 01 I I 1 W-.{~ ~0 PRODUCTION PROFILE 9 61 00 6 I 1 X-19B BRIDGE PLUG RFC.DEPTH DET. 9 6 0 90 3 I 1 X-19B PBI . BRIDGE PLUG RFC.DEPTH DET. 9 60 901 I 1 Y-28 STATIC PRESSURE SURVEY 9 61 01 5 I 1 Y-34 STATIC PRESSURE SURVEY 9 61 01 5 I 1 Z-01 PRODUCTION PROFILE 9 61 00 7 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received" bY:.~.(-~' ''~)~''') - GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10502 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 10/18/96 %t- Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Disk D.S. 14-16 96280 CNTG ~ ~!"-/~ 960922 1 D.S. 14-31 96281 CNTG ¢ ~ ! ~<~ 960922 1 D.S. 15-44 96260 TDT-P ¢"'7/-7-7 960831 I A!ss,ka 0it & Gas Cons. Commission ~ch0r~e Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL C-21 (32-19-11-14) P-01 (33-27-'11-13) '-13 B-02A DESCRIPTION 1 PFC/PERF FIELD BL+RF 1 CN FINAL BL+RF 1 GR/CCL FINAL BL+RF I PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PDK FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run # 1 4352.05 Run # 1 5789.02 Run # i 5851.03 Run # 1 5863.07 Run # 1 6054.08 Run # 1 6619.01 Run # 1 6625.01 Run # 1 6631.02 Run # 1 6654.06 Run # 1 6679.01 Run # 1 6721.07 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOP~AGE AK, 99501. Date: 15 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL A-16A DESCRIPTION LDWG TAPE+LIS LDWG TAPE+LIS ECC No. Run # 1 6721.02 Run # 1 6733.01 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 563-7803 Received by: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOR.AGE AK, 99501. Date: 5 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION B-02A 1 DIFL FINAL BL+RF 1 BHC/AC FINAL BL+RF 1 CN FINAL BL+RF ! ZDL FINAL BL+RF 1 BH PRO FINAL BL+RF 1 SSVD FINAL BL+RF Run # 1 Run # ~ Run # 1 Run ~ 1 Run # 1 Run # 1 ECC No. 6721.02 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201. Anchorage, AK 99518 Received by Date: RECEIVED AUG ] 2 1996 Alaska Oil & Gas Cons. Commiss~ Anchorage HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOR.AGE .. AK, 99501. Date: 9 July 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL $ DESCRIPTION 1 CCL FINAL BL+RF / Run # 1 ~ ~7 W-11 (14-28-11-12) 1 PLS FINAL BL+RF/ 1 PLS FINAL BL+RF j 1 PLS FINAL BL+RF Run # 1 Run # 1 Run # 1 1 PLS FINAL BL+RF Run # 1 1 PLS FINAL BL+RF Run # 1 1 PLS FINAL BL+RF~-~ Run # 1 1 GR/CCL FINAL BL+RF u-- Run # 1 1 PFC/PERF FINAL BL+RF /Run # 1 q~LLt B-02A ~"~( B-02A 1 CCL FINAL BL+RF ~ 1 SBT/GR FINAL BL+RF Run # 1 Run ECC No. 4298.04 5642.03 5792.02 5829.02 5829.03 5938.06 6685.02 6720.00 6721.00 6721.01 Received by: Please si~n and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Date: RECEIVED JUL 1 9 1996 ~ctx~'age MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David John~n, Chairm~¢"~ Blair Wondzell, ~ FROM: Bobby Fdster~V",,,/' [ SUBJECT: Petroleum Inspector DATE: July 1, 1996 FILE NO: AJIlGADD.doc BOPE Test - Doyon 16 BPX - PBU - A-02A PTD # 96=0111 Prudhoe Bay Field Monday, July 1, 1996: ! traveled this date to BPX's PBU well A-02_A and being side tracked by Doyon rig 16 and witnessed th einitial BOPE test. As the attached AOGCC BOPE Test Report shows the test went good with the . exception of the low level gas gas alarm ( flashing light) would not activate on the H2S and methane at the shale shaker and at the bell nipple on the methane detector. The alarms worked properly on high alarm. This will be corrected and I will be notified. The rig was clean and all equipment seemed to be in good working order. The location was clean and all extra equipment was stored properly. Summary: I witnessed the BOPE test on Doyon rig 16 side tracking BPX's PBU well A-02 - test time 2.5 hours - 1 failure. Attachment: AJIIGADD.XLS X UnclaSsified ,, Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial X Workover: DOYON Rig No. 16 PTD # 96-111 BPX Rep.: B-O2A Rig Rep.: Set (~ 8859' PBD Location: Sec. 31 T. Weekly Other DATE: 7/1~6 Rig Ph.# 659-4610 M. JACKSON BOBBY INGRAM 11N R. 14E Meridian Urn. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gert) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP 1 Ball Type 1 , Inside BOP I Quan. Test Pressure 250/5,000 250/5,000 250/5,000 250/5,000 BOP STACK: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams ~ Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves 1 Check Valve N/A Quan. Test Press. 250/3,000 1 250/5000 I 250/5000 250/50OO 250/5,000 P/F P P P P P P P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES CHOKE MANIFOLD: No. Valves 14 No. Flanges 36 Manual Chokes 1 Hydraulic Chokes 1 Test Pressure P/F 250/5,000 P 250/5000 P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 6 @ 2100 3,000 I P 1, 750 . P minutes 28 sec. minutes 28 sec. YES Remote: YES Psig, Equipment will be made withi'"-~ I days"-~. N' - otify the Inspector and follow with Writt'"~"'en or Faxed verification to Jthe 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 I I I I I II I I REMARKS: ,,,,Failure' The flashing warning light would n. ot come on at Iow level alarm on the H2S and methane detectors at the shale shaker and flashing light would not come on at the bell nipple on the methane detector'. To be repaired and the i..nspector notified. Ali lights and alarms worked on high level. ~ Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: VVitnessed By: BOBBY D. FOSTER FI-021L (Rev.12/94) AJIIGADD.XLS TONY KNOWLE$, GOVEF~NOR ALASKA OIL CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 9950!-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 18, 1996 Dan Stoltz Sen/or Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit B-02A BP Exploration (Alaska) Inc. Permit No. 96-111 Sur. Loc. 961'SNL, 1598'WEL, Sec. 31, TllN, R14E, UM Btmnhole Loc. 3497'NSL, 391'WEL, Sec. 32, T1 IN, R14E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 65%3607. David W. T6~on ~ ~ Chairman ~ BY ORDER OF THE COMMISSION dlffEnclosures. CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmcntai Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request:'D Abandon [] Suspend [] Plugging f-i Time Extension '~ Perforate [] Alter Casing [] Repair Well [] Pull Tubing ~ Variance i~ Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well ~ Stimulate Plug Back for Sidetracl~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: i~ Development [] Exploratory [] Stratigraphic [] Service Datum Elevation (DF or KB) KBE = 59.72 AMSL 7. Unit or Property Name Prudhoe Bay Unit Well Number B-02 4. Location of well at surface 8. 961' SNL, 1598' WEL, SEC. 31, T11N, R14E 9. At top of productive interval 2326' NSL, 2026' EWL, SEC. 32, T11N, R14E At effective depth 1998' NSL, 2142' EWL, SEC. 32, T11N, R14E 11. At total depth 1945' NSL, 2226' EWL, SEC. 32, T11N, R14E Permit Number 70-20 10. APl Number 50-029-20066 Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10755 feet Plugs (measured) /:,r ''i 9187 feet '~'"-~/ 10546 feet Junk (measured) Fill at 10546' MD BKB (11/89) 9004 feet Casing Length Size Cemented MD 'I-VD Structural -- Conductor 109' 30" 150 sx 128' 128' Surface 2289' 20" 5100 sx 2308' 2308' Intermediate 4526' 13-3/8" 1200 sx 4545' 4339' Production 10705' 10" 2460 sx 10724' 9162' Liner 4595' 7" 2090 sx 5988' - 10583' 5467' - 9049' R, CE1VED Perforation depth: measured 10502' - 10554' ' Sqzd: 10280' - 10288', 10406' - 10452', 10462' - 10482', 10492' - ,1.Q502~' ,.¢,..~ '.~ / ?_ !996 true verticalsubsea 8925' - 8966' Tubing (size, grade, and measured depth) 7, L-80 to 2990'; 5-1/2", L-80 2990' - 5946' with~4-'l/2' Packers and SSSV (type and measured depth) 9-5/8" BOT packer at 5946'; 7" Otis WD packer at 9720' with TP assembly; 5-1/2" SSSV at 3002' 13. Attachments l~ Description summary of proposal [] Detailed operations program -- BOP sketch 14. Estimated date for commencing operation June 20, 1996 16. If ~roposai was verbally approved 15. Status of well classifications as: [] Oil [] Gas ,~ Suspended Service Name of approver Date approved Contact Engineer Name/Number: Mark Johnson, 564-5480 Prepared By Name/Number Terrie Hubble, 564-4628 17. I hereby certify that th,ed"~'egoin~ tr~e a,~ ~rrect to the best of my knowledge Signed // // ~.,~' ~ Tern/Jordan ./{"/__~'////~"'/1'__......~/'~"~~(___~ Title Senior Drilling Engineer Commission Use Only Date ¢////~; ¢· Conditions of Approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- I Approval No. C}~ _/c,,3 ~ Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 68.5' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028310 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 961' SNL, 1598' WEL, SEC. 31, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3703' NSL, 1017' WEL, SEC. 32, T11N, R14E B-02A At total depth 9. Approximate spud date Amount $200,000.00 3497' NSL, 391' WEL, SEC. 32, T11N, R14E 06/21/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028309 391'I No Close Approach 2560 12277' MD / 9049' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 5696' MD Maximum Hole Angle 81 o Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 BTC-Mod 6736' 5541' 5101' 12277' 9049' 500 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface IntermediateR E C E IV E D Production Liner JUN I 2 1996 Alaska 011 & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5480 Prepared By Name/Number Terrie Hubble, 564-4628 21. I hereby certify that th/e"iore¢oing is tru~,C~/d c/~ect to the best of my knowledge Signed{ . ,,,/~_ ~/~..///' DanStoltz .-~'.~V~-----'¢*",. ¢2'~"~'~(¢~ Title Senior Drilling Engineer Date Z Commission Use Only Permit Number I APINumber I ApprovqlDate [ Seecoverletter ~'~/'.-.-////// 50- O,~. ¢-'" ~__~. 4:~(::~'~'- d::~ / (.¢//¢~ for other requirements Co'nditions of Approval: Samples Required [] Yes ~ No Mud Log Required' [] Yes ~8' No Hydrogen Sulfide Measures ,,~s [] No Directional Survey Required ~Yes [] No Required Working Pressure forBOPE []2M; []3M; I~ SM; [] 10M; [] 15M Other: ¢¢igirl;9.1 Signed By by order of Approved By q,~ir{ IA! Inhn~fnn Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit i '1 l)licate Well Name: I B-02A Redrill Plan Summary Type of Redrill (producer or injector): ] Producer Alaska 011 & G~ Con~. Commission Anchorage Surface Location: 961' FNL 1598' FEL S31 T11N R14E UM Target Location: 3703' FSL 1017' FEL S32 T11N R14E UM Bottom Hole Location: 3497' FSL 391' FEL S32 T11N R14E UM I AFENumber: 14P0833 I I Rig: I Doyon 16 I I Estimated Start Date: 16/21/96 I i Operating days to complete: 125 I Ira): ! 12277 I IrvD: 19049' I II~: 168.5' I I Well Design (conventional, slimhole, etc.): I High Angle Sidetrack I Objective: ] Target new BHL. Current BHL is fully depleted. Mud Program: Special design considerations I Gel-free 6% KC1Biozan Fluids I Density PV YP INT 10MIN FL OIL SOLIDS (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) ,I" KOP 9.9-10 14 55 30 40 7 0 7 to to to to to to to to to TD 9.9-10 15 LSR 5 20 30 5 0 7 Directional'. I KOP: 1 5696' MD Maximum Hole Angle: I 81 o Close Approach Well: I NONE Casing/Tubing Program: Hole Size Csg/ WtfFt Grade Con Length Top Btm Tbg O.D. n MDfrVD MDfrVD 8.5 7" 29# L-80 BTC- 6736' 5541/5101 12277/9049 m Tubing 4.5" 12.6// L-80 IBT-M 11520' 0/0 11520/8879 RECEIVED JLtI,~ 1Z i99G Cement Calculations: Liner Size: 7" A .... Basis: Calbula~e cement ~olume to bring top of cement 1000' above top of Sag Riv~i:~'fi~'i~fg 50% open hole excess, 80' shoe joint. Total Cement Volume: @ 500 sxs of Class G Blend @ 1.19 ft3/sx I I I Basg:I Total Cement Volume: Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Hazards: H2S: B pad is not an H2S pad. Last reading on B-02 was 5 ppm (5/95). Pore Pressure: Sadlerochit pore pressure is expected to be -3439 psi at 8800' TVDSS or equivalent mud weight of 7.52 ppg, The maximum anticipated surface pressure assuming 0.1 psi/ft gas gradient is 2559 psi. Lost Circulation: Potential LC when cutting through the Sag/Shublik interfaces. SUMMARY REDRILL PROCEDURE: 10. 11. 1. The well was P&A'd pre-rig. Move in drilling rig. Test 10 3/4" casing pack-off. 2. Pull BPV. Circulate diesel freeze protection cap from well. 3. Install TWC. Test to 1000 psi. Remove the production tree. 4. Install BOP's and test to 250 psi/5000 psi. Remove TWC. 5. Pull and lay down the 7"x 5-1/2" tubing from the jet cut (5896') to surface. Test casing and pre rig P&A to 3000 psi. 6. Set cement retainer at 5890'. 7. Spot 18 ppg mud and displace to milling fluid. 8. Section 9-5/8" casing starting @ -5691'. 9. Spot a balanced cement kick-off plug (165 cubic feet minimum) through open- ended drillpipe from 100' below the base of the section to 200' above the top of the section. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to the target per the attached directional plan. At TD run triple combo logs on DP. Run a 7" 29# L-80 liner assembly to bottom in the 8-1/2" hole and space the liner hanger about 150' up inside the 9-5/8" casing. 12. 13. 14. 15. 16. 17. Cement to 1000' MD above the top of the Sag River using 50% open-hole enlargement plus the 80' shoe volume. Estimated cement volume is 500 sxs using 1.19 yield. P/U 6" bit and clean-out 7" liner to landing collar. Displace to clean seawater. Run the 4-1/2" L-80 completion string assembly and set packer. Test tubing to 4000 psi for 30 minutes. Test annulus to 3000 psi for 30 minutes. Install and test the production tree to 5000 psi. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. RECEIVED JUN 1 ~i 1996 Alaska Oil & Gas Cons Anchorage ~Well ......... : B-02A Field ........ : Prudhoe Bay, B-Pad Computation..~ Minimum Curvature Unica ........ : FEET Surface Lat,.: 70.26889178 N Surface Long.: 148.67337225 W Legal Description Surface ...... : 4318 FSL 1598 FEL Tie-ih Survey: 3979 FSL 129 FEL BSL .......... : 3703 FSL 1017 FEL ESL .......... : 3518 FSL 455 FEL BHL .......... : 3497 FSL 391 FEL Anadrill Schlumberger Alaska DistricC 111i East 80th Avenue Anchorage, AK 99518 349-4511 Fax 344-2160 ANADRILL AKA-DPt- APPROVED FOR PERMI' iNG ONLY PLAN DI~I~ WE~ P~ for S~ED S~VICES DRI~IN~ ~ LOCATIONS - ALASKA Zone: · X- Coord Y- Coord S31 T11N R14E UM 664041.08 5949689.38 S31 TllN R14E U~[ 6655~7.~· 59~93~1.7: S32 T11N R14E UM 669916'.~0 59492~4.00 s32 Tl~.14E t~ 670483;00 5949032.00 532 T~IN ~14~ u~ 670547.13 594901~.ss Prepared ..... : 06/10/96 Vert sect az.: 108.12 KB elevation.: 6e.SO f~ MagnecAcD~ln:.+28,418 Scale ~ac~or.: 0.99993057 Convergence..: +1.24876346 PROPOSED WELL PROFILE utltmmmmmmmmmmmaamam mmmmm mmmmmm STATION MEAS INCLN IDENTIFICATION DEPTH AN~LE TIE-IN SURVEY 5609 39.25 ~P OF WINDOW 5691 38.84 KO~ / CURVE 6/100 5696 38.81 5700 38.88 5800 40.80 5900 43.36 F-ND CURVE 6/100 5914 43.75 WS2 6337 43.75 CM3 6843 43,75 CMl 8497 43.75 8933 ·3.75 (Aa&cLrill (c)g~ B02A.9S ].0b.03 11:S2 AM P) smmmmmmmm mmmammaammm mmmml DIRECTION VERT-DEPTHS SECT AZIMUT~ TVD SUB-S DIST 108,00 SIS6 5087 1503 107.18 5219 5151 1554 107.13 5223 5155 1S58 106,76 5226 5158 1560 97.88 5303 S235 1624 89.77"' S378 S309 1688 88.72 S388 S319 1697 88.72 ".5694 5625 1974 88.72'%.. 6059 5990 2303 88.72 7254 7185 3382 88.72 7569 7500 3667 ammmaJamummmmmmmaammm COORDINATES-FROM mmmmmmmmmm mmaaamam~m 339.80 S 1469.91 355.45 'S 1519.26 356.37 S 1522.26 357.10 8 1524.66 370.65 S 1587.13 375.00 S 1653.88 E 374.89 S 1663.36 E 368.34 8 1956.21 E 360.5S S 2305.54 E 335.04 S 3449.25 E 328.31 S 3750.72 STAT~-PLAN~ TOOL DL/ X Y FACE 100 665517.94 S949381.72 129L <TZE 665567.62 S949367.15 128L 0.80 665570,64 S949366.29 75~ 0.80 665573.05 5949365.61 75L 6.00 665635.80 5949353.43 68L 6.00 665702.63 5949350.54 665712.09 5949350.87 666004.72 5949363.78 666353.77 S949379.18 667496.57 5949429.61 667797.81 5949442.90 62L 6.00 6.00 0.00 0.00 0.00 0.00 B-02A (PS) PROPOSED WElL PROFILE O6/lO/96 Page 2 c STATION MEAS INC~N DIRECTION IDERTIFICATION DEPTTd ARGLE AZI~gu~i'H '~ T~/ ~ /P~ RI~R 9189 43.75 88.~2 T~ 9715 43.75 88.72 T~ 99~ ~3.vs ~,~ ea.v2 VERT-DEPTHS SECT T~ SUB-S DIST 7754 7665 3834 8134 8065 4177 8314 8245 4339 8509 ~ 4516 8539 8470 4543 TSAD 10387 43.75 88,72 8619 85_~50 4615 CU~V~ 10/100 10402 43.75 88.72 8630 8561 4625 10500 52.36 94.91 8695 8627 4695 10600 61.47 99.89 8950 8681 4779 10700 70.72 104.07 8790 8722 4868 10800 80.05 109.80 END CURVE 10/100 10809 80.89 108.12 TZ3 10851 80.89 108.12 TZ2C 11356 80.89 108.12 CC~ 11483 80.89 106.12 BSL 11609 80.89 108.12 TZ2B 11641 80.89 108,12 2SN 11893 80,89 108.12 24N 12114 80.89 106.12 HOT 12127 80.89 108.12 8o.89 loe.12 80.89 106.12 80.89 106.~2 ESL 12209 7" C~LNQ PT 12277 TD 12297 COWC {X~a~rll~ {c) 9{ B02A~S 3.0b.03 I~:52 A]~ J)) 8815' 8747 4964 8819 8948 4973 8824 8755 5015 8904 8835 5514 8924 8855 5638 8944 8875~/5763 8949 8880 5794 8989 8920 6044 9024 8955 . 6262 9038 8970%/ 6356 9049 8981 6423 9049~ 6423 9085 9016 9159 9090 COORDINATES-FROM 324.36 ~ 3927.78 316,25 S 4291.47 312,41 S 4463,74 308.25 S 4650.37 307.61 S 4679,09 305.90 S 4755.65 E 305.66 S 4766,46 E 308.23 S 4839.01 E 319.19 S 4921.95 E 338.27 S 5011.23 E 364.87 S 5104.14 367.62 S 5112.63 380.50 S 5151.99 535.73 S 5626.23 574.53 S 5744.79 613,34 S 5663.35 623.04 S 5892.99 700.65 S 6130.10 768.56 S 6337.58 972.44 $ 6349,44 797.67 S 6426.50 818.52 S 6490,20 818.52 S 6490.20 mmmmmmlmmmmmmmmmmmmm mmmm mmmm STAT~-PLA~ TOOL DL/ X Y FACE 100 mmmmmmmmm mmmmmmmmmm mmmm mmmm 667974.73 5949450.71 0.00 668338.13 5949466.94 0.00 668510,27 5949474.34 0.00 668696,75 5949462.57 0.00 668725.44 5949483.83 0.00 668801.94 5949487.21 0.00 668812.76 S949487.69 30R 0,00 668885.33 5949486.70 26R 10.00 666968.48 5949477.54 23R 10.00 669058.15 5949460.42 22R 10.00 669151.61 5949435.85 21R 10.00 669160.15 594943~.29 10.00 669199.79 5949421.26 0,00 669677.26 5949276.42 0.00 669796,63 5949240.21 0,00 669916.00 5949204.00 0.00 669945.84 5949194.95 0.00 670184.56 5949122.53 0.00 670393.47 5949059.16 0.00 670405.41 5949055.54 O.O0 670483.00 5949032.00 0.00 670547.13 5949012.55 0.00 670547.13 5949012.55 0.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # ,$' -- 7~00 ....... SH'A'R'E'D 'SERVICES DRILLING I II ~! I II I I II ii i iiii · iii i I ii i iii I I III I! i I iiiii i. ,4nadf'.i ] ] S£h]ucberger I I II II I IIii IIII I I I I II iiii · ! i i ii B-O2A (PS) VERTICAL SECTION VIEW Sect ion at: 108.12 ', IiTVD Scale · I inch = 800 feet ', Oep Scale.' I inch = 800 feet ,..,~'-~ .... Bt'awn ' 06/!0/96 ~ ' 'NN- . ± .i.,.,::. ~ ..... Marker Identification MO ~B SECIN INCL ~'~9i A) TIE-IN SURVEY 5609 5i56 1~3 39.2 B) TOP OF WIDOW 5691 52i9 i554 3B.~ C) KOP / CURVE 6/~00 56~ 5223 ~55B 38.8 ~- --- -~,~. ' ' D) END CURVE 6/i00 5914 5388 1697 43.7 '~'~¢ .... E) C~VE tO/lO0 I040~ ~30 4625 43.7 F) END C~VE lO/tO0 iOBO9 ~17 4973 80.~ ............ G) BSL i i~9 B944 5763 80.E ~ H) ESL 1~209 9038 6356 80.E ~ I) 7' CASING PT 12277 9049 6423 80,E ~ J] TO 12~77 9049 6423 BO.~ ~ ........... ~ ....... ,- -, ................ AN~kDRILL -',.? ~¢ ....... ~ ........ .... FOR PERi~IT!'ING ~-~ , ON LY ,~-~,~ , PLAN ~,~ ~,~ ,~%' :t~=~=====: ===== = ~= .... ' c' ~~ .......... ~~ ~ ~ ~ ,~~ ==~ I I.~ i I I I I I t ~ I ! I I i ~ ...... I ! ! ~I I I I I I i I I ~ ' o i i ! '_~'. i200 1600 2000 2,400 cr~l) (c)96 ~2~ 3.0~.03 !1:54 AMP) 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 Section Depa.rtuce .............. '1 Anadr j ] 1 Sch]umberger · B-02A (P5) PLAN VIEW LOSURE 6542 feet at Azimuth 97 19 ECLI CALE RAWN ~PkeP ~IE-I TOP ENO CU~¥ E~0 BSL ESt 7' TO i i ' SHAREO .... sERvICES-DRIE-LI G i i iiii i i ..... i i ii! !11111 iii i ~ iii ii i s i i iii i i i ~ATION.' +28.418 (E) · 1 inch : 800 feet · 061~0/96 ...... ,, . i ~ IOentification MD N/S E/W ...... ',_, _' -- ,, , · IN SURVEY 5609 34O S 12209 798 S 6427 E ............... ]2277 819 S 64~ E - :.. _ ............ ~_.~ , .... KB ............. ................ ~. .......... I1 , ] .. , . ·; %% .......... 400 0 t00 800 1200 600 2000 2400 2800 3200 3600 t000 t400 4~0 5200 5600 6000 6400 6800 <- WEST' EAST-> I FIELD & POOL Vt r"L~.. Pr'~--iivli i CH.-,.,KL~o, ADMINISTRATION GEOLAREA , , 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 drtg unit boundary .... 6. Well located proper distance from other wells ........ 7. Sufficient acreage available in drilling unit ........... 8. tf 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 ...... Permit can be issued without administrative approval .... Can permit be approved before 15-day walt ......... ~, ~ .. UNIT# ./i/'~,~,_~'~:~ ON/OFF SHORE ~ '4.2 REMARKS ENGINEERING APPR DATE 14. Conductor string provided .................. ,/o N 15. Surface casing protects all known USDWs . ................' N 16. CMT vol adequate to circulate on conductor & surf csg . . . N 17. CMT vol adequate to fie-in long string to surf csg ...... N 18. CMT will cover all known productive horizons. N 19. Casing designs adequate for C, T, B & permafrost. ....... N 20. Adequate tankage or reserve pit ................ N 21. If a re-drill, has a 10403 for abndnmnt been approved... ""Y,-2 N 22. Adequate wellbore separation proposed ........... i r,~ N 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schematic & equip list adequate .... ~/~ N 25. BOPEs adequate ...................... LY,4 N · °..... 26. BOPE press ralJng adequate; test to ,,52 ~0(~)_ Dsig. ,¢~ N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ¢ N 28. Work will occur without opera~Jon shutdown .......... ~'" N 29. Is presence of H2S gas probaJ~le ............... GEOLOGY can be issued w/o hydrogen sulfide measures ..... Y N/,~. ) ,~ 30. Permit 31. Data presented on potentiaJ over~ressure zones ....... Y/4q //~ (~ 32. Seismic analysis of shallow gas :~ones ............. /Y N ' 33. Sea. Ued condition survey (if off-shore) ........... .//Y N 34. Con,ct name/phone for weekly progress reports .... /.. Y N [dx~i'ora,'ory on,~z'] ~' ENGINEERING: CO .MMISSIO ~_[~-- JDH / JDN TAB Commems/ir~sU'uctions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORAION WELL NAME : B-2A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292006601 REFERENCE NO : 97076 Date_ LIS Tape Ve~cation Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/04/14 ORIGIN : FLIC REEL NAi~E : 97076 CONTINUATION # : PREVIOUS REEL : CO~94ENT : BP EXPLORATION, B-2A, PRUDHOE BAY, API #50-029-20066-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/04/14 ORIGIN : FLIC TAPE NAME : 97076 CONTINUATION # : 1 PREVIOUS TAPE CORff4ENT : BP EXPLORATION, B-2A, PRUDHOE BAY, API #50-029-20066-01 TAPE H~ER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: B- 2A API NUMBER: 500292006601 OPERATOR: BP EXPLORAION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 31-MAR-97 JOB NUMBER: 97076 LOGGING ENGINEER: J. PAWLUK OPERATOR WITNESS: S. WHIPP SURFACE LOCATION SECTION: 31 TOWNSHIP: 1 iN RANGE: 14E FNL : 961 FSL: FEL: 1598 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 59.70 DERRICK FLOOR: GROUND LEVEL: 40.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT)WEIGHT (LB/FT) 1ST STRING 9. 625 5663.0 2ND STRING 7.000 10385~0 3RD STRING 4. 500 10171 . 0 12.60 PRODUCTION STRING 4. 500 12283.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Ve~_~cation Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 2 9-JULY- 9~ LOGGING COMPANY: ATLAS BASELINE DEPTH 88888 0 12095 5 12090 0 12071 5 12053 5 12041 5 12025 5 12015 5 12008 0 12001.0 12000.5 11995.5 11984.5 11958.5 11958.0 11938.0 11936.0 11927.0 11914.0 11911.5 11885.0 11880.5 11865.0 11856.0 11854.5 11847.5 11823.5 11811.0 11751.0 11711.5 11695.0 11683.5 11679.0 11677.5 11660 5 11629 0 11617 0 11612 0 11595 5 11595 0 11593 5 11585.0 11568.0 11565.0 11557.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88886.5 88887.0 12094.0 12088.0 12071.0 12039.5 12024.5 12015.0 12007.0 12000.5 11994.0 11985.5 11959.0 11934.5 11912.5 11879.0 11864.5 11855.0 11847.5 11823.5 11812.0 11749.5 11711.5 11695.5 11683.5 11678.0 11659.0 11629.0 11612.0 11595.0 11592.0 11583.0 11567.0 12052.5 12000.0 11959.0 11941.0 11928.5 11910. 5 11884.5 11854.5 11678.0 11616.5 11595.0 11567.0 11559.0 PAGE: LIS Tape Ve;__ication Listing Schlumberger Alaska Computing Center 11546.5 11545.5 11545.5 11545.5 11507.5 11506.5 11493.0 11492.0 11442.0 11441.0 11435.5 11434.5 11428.5 11426.5 11425.5 11425.0 11409.0 11408.0 11400.0 11400.0 11373.5 11373.0 11371.0 11373.0 11360.0 11359.0 11359.0 11357.5 11348.0 11346.5 11331.0 11329.5 11329.5 11329.0 11307.5 11305.5 11301.5 11301.0 11295.0 11294.0 11279.5 11279.5 11253.5 11252.5 11219.0 11217.5 11216.5 11215.0 11195.0 11194.0 11173.5 11171.0 11157.5 11156.5 11138.0 11136.0 11104.0 11103.0 11096.5 11095.5 11096.0 11095.5 11062.5 11062.5 11043.5 11043.5 11027.5 11028.0 11011.5 11011.5 10995.5 10996.0 10964.0 10963.0 10910.5 10909.0 10888.0 10886.5 10883.0 10881.5 10875.5 10873.0 10842.5 10842.0 10841.5 10827.0 10826.5 10819.5 10819.0 10808.5 10807.5 10807.0 10807.5 10777.0 10776.0 10775.5 10776.5 10760.5 10759.5 10744.0 10743.0 10743.5 10742.5 10739.5 10738.0 10738.5 10738.5 10735.0 10734.0 10734.5 10735.0 10731.0 10730.5 14-APR-1997 13 '. 35 PAGE: LIS Tape Ve~__lcation Listing Schlumberger Alaska Computing Center 10730.5 10710.5 10709.5 10697.5 10696.0 10692.0 10691.0 10680.5 10674.5 10660.5 10660.0 10647.5 10644.5 10638.5 10631.5 10630.5 10601.5 10594.0 10593.5 10582.5 10581 0 10568 5 10567 5 10560 0 10549 5 10545 0 10544.5 10543.5 10539.0 10524.0 10523.5 10514.5 10496.0 10495.0 10490.5 10486.5 10486.0 10463.0 10453.5 10453.0 10448.5 10448.0 10436.5 10432.5 10425.0 10424.5 10411.0 10402.0 100.0 $ 10709.5 10696.0 10690.5 10679.0 10672.5 10659.5 10645.0 10638.0 10629.5 10600.5 10592.5 10581.0 10566.0 10558.0 10548.0 10542.5 10539.0 10534.5 10521.5 10513.5 10494.0 10488.5 10484.5 10461.0 10451.5 10446.5 10434.5 10423.5 10409.0 10400.5 98.5 10729.5 10709.0 10695.5 10690.5 10659.5 10645.0 10629.5 10592.5 10581.0 10566.0 10542.0 10521.5 10493.5 10484.5 10460.5 10451.5 10446.5 10432.5 10423.5 99.0 RE~RKS: 14-APR-1997 13:35 CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON BP EXPLORATION'S B-2A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN BASELINE PASS #1 GRCHAND GR.BCS; AND BASELINE PASS #1 SIGMAND GR.BCS. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. PAGE: LIS Tape Ver~cation Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 *NOTE: THIS IS A "REDO" JOB. IT HAS BEEN EDITED TO ADD- RESS: (1) A MISSING COMMENT STATEMENT IN FILE #2, AND (2) INCORRECT PASS H/FILE # PAIRINGS. THESE PROBLEMS HAVE BEEN CORRECTED. IN ORDER TO INCLUDE THE COM~4ENT STATEMENT ON THE HARD-COPY LISTING OF FILE #2, THE NU~ER OF DEPTH SHIFT PAIRS WAS REDUCED. THE NEW DEPTH- SHIFT MONITOR PLOT IS INCLUDED FOR YOUR INSPECTION. A SIMPLE EDIT OF THE FILE HEADERS CORRECTED THE PASS #~FILE # PAIRINGS. THE DATA WAS NOT AFFECTED BY THAT PORTION OF THE EDIT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUAfBER : 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUNk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12153.0 10236.0 TDTP 12182.0 10236.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NU~ER : BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP REMARKS: THIS FILE CONTAINS TDTP BASELINE PASS Hi. THERE WERE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Vez~ication Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TRATTDTP 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TSCNTDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Ver=~ication Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: ** DATA ** DEPT. 12181.000 SIGM. TDTP SBHN. TDTP 52.347 SIGC. TDTP SDSI.TDTP 0.196 BACK. TDTP TCAF. TDTP 32521.676 TCND. TDTP TSCF. TDTP 5271.516 INND. TDTP TENS.TDTP -70.000 CCL.TDTP DEPT. 10234 SBHN. TDTP -999 SDSI.TDTP -999 TCAF. TDTP -999 TSCF. TDTP -999 TENS.TDTP -999 12.921 TPHI.TDTP 25.030 SBHF. TDTP 49.441 O. 422 SIBH. TDTP 79. 646 TRAT. TDTP 1 . 907 83 . 983 FBAC. TDTP 26. 418 TCAN. TDTP 77948.125 31701 . 223 TCFD. TDTP 10949. 695 TSCN. TDTP 12634 . 797 839. 859 INFD. TDTP 376. 876 GRCH. TDTP -999. 250 O. 000 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 250 BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP -999. 250 250 TCND. TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 250 INND. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP 57. 844 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NIrM~ER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH GRCH 12146.0 TDTP 12175.0 STOP DEPTH .......... 10246.0 10246.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12161.5 12149.0 12138.5 12133.0 12111.5 12110.5 12106.5 12104 5 12098 5 12092 5 12084 5 12078 5 12065 0 12060 5 12056 5 12052 5 12040 0 12037 5 12034 5 12024 0 12014 5 12012 0 12000.0 11986.5 11978.5 11972.5 11968.5 11966.5 11958.0 11950.5 11938.0 11910.5 11892.5 11884.5 11878.5 11871.5 11864.5 11862.5 11860.0 11858.5 11855.5 11853.0 11846.5 11831.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH 88888.0 12111.5 12103.5 12092.0 12084.0 12060.0 12055.5 12039.5 12036.5 12024.0 12011.5 12000.5 11972.5 11968.0 11892.0 11884.0 11878.5 11871.0 11864.0 11859.5 11855.5 11847.0 TDTP 88887.0 12160.5 12148.0 12138.0 12133.0 12110.0 12106.5 12097.5 12077.5 12065.0 12052.5 12034.0 12014.0 11986.5 11979.0 11966.5 11959.5 11952.5 11941.0 11909.5 11878.0 11861.5 11858.0 11853.5 11832.0 LIS Tape Ver~_~cation Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 11818.5 11816.5 11814.5 11798.0 11782.5 11774.5 11766.5 11755.5 11722.0 11716.5 11708.5 11706.5 11704.5 11702.0 11700.5 11696.5 11688.5 11679.0 11676.5 11672.5 11668.5 11668.0 11664.5 11660.5 11654.5 11650.5 11626.5 11620 5 11618 0 11595 0 11592 0 11584 5 11578 5 11570 5 11566 5 11562 0 11559 0 11550.5 11546.0 11538.5 11532.5 11524.5 11522.5 11512.5 11494.5 11482.5 11460.5 11451.5 11436.0 11426.5 11420.5 11416.0 11394.0 11375.0 11358.5 11816.5 11718.0 11710.0 11705.5 11702.0 11698.0 11689.0 11672.5 11669.0 11665.0 11660.5 11621.0 11584.0 11532.0 11524.0 11511.5 11458.5 11420.0 11818.5 11814.0 11797 5 11780 5 11774 5 11766 0 11754 0 11719 0 11705.0 11700.5 11677.5 11674.5 11666.5 11653.5 11649.0 11626.0 11617.5 11595.0 11590.5 11580.5 11571.0 11567.0 11564.0 11559.0 11552.0 11545.5 11537.5 11522.5 11493.5 11480.5 11450.0 11434.0 11426.0 11416.0 11393.5 11373.5 11356.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 10 11352.5 11340.5 11338.5 11330.5 11302.5 11300.5 11298.5 11286.5 11262.5 11246.5 11238.5 11216.5 11206.5 11194.5 11190.5 11178.5 11161.0 11135.5 11118.0 11096.5 11074.5 11054.5 11042.5 11018 5 11007 5 10995 5 10978 0 10954 5 10944 5 10942 5 10940 5 10926 5 10920 5 10914 5 10906.5 10892.5 10881.0 10874.5 10860.0 1O850.0 10848.5 10842.5 10834.5 10832.5 10822.5 10818.5 10810.5 10809.0 10804.5 10798.5 10792.5 10784.5 10782.5 10778.5 10774.5 11351.0 11339.0 11299.0 10942.5 10938.5 10918.0 10890.0 10858.5 10850.0 10831.5 10807.5 10803.5 10790.5 10782.5 10776.0 11337.5 11329.5 11301.5 11297.5 11285.5 11262.0 11245.5 11237.5 11215.0 11205.0 11193.5 11189.5 11177.5 11159.5 11134.5 11117.5 11096.0 11073.5 11054.0 11043.0 11018.5 11006.5 10996.5 10978.0 10953.5 10941.0 10926.0 10913.0 10905.5 10880.5 10873.0 10847.5 10841.0 10833.5 10822.0 10818.0 10810.5 10798.5 10783.0 10774.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 11 10772.5 10762.5 10746.5 10744.5 10739.5 10738.5 10731.5 10724.5 10715 5 10700 5 10692 0 10691 5 10660 5 10645 0 10630 5 10628.5 10618.5 10602.5 10594.0 10582.0 10576.5 10574.5 10569.0 10567.0 10555.0 10545.0 10538.5 10530.5 10524.0 10494.5 10490.5 10487.0 10466.5 10454.5 10454.0 10449.0 10433.5 10432.5 10428.5 10425.5 10425.0 10412.0 10408.5 10400.5 10396.5 10392.5 10388.5 10386.5 10386.0 10381.5 10379.0 10376.0 10368.5 10362.5 10346.0 10771.0 10743.0 10738.5 10730.5 10723.0 10714.5 10698.5 10690.5 10658.5 10626.0 10592.5 10574.5 10566.0 10522.0 10484.5 10451.5 10446.5 10430.0 10426.5 10423.5 10406.5 10399.0 10394.5 10391.0 10386.5 10384.5 10379.5 10374.0 10361.0 10344.0 10761.0 10745.0 10738.0 10690.5 10660.0 10645.0 10629.0 10617.0 10601.0 10592.5 10581.5 10573.0 10566.5 10552.0 10542.0 10535.5 10527.5 10521.5 10492.0 10488.5 10464.0 10452.5 10433.0 10424.0 10410.0 10385.0 10378.0 10367.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 12 10337.0 10333.0 10330.5 10330.0 10319.5 10318.5 10313.0 10304.0 10298.0 10288.5 10286.5 10284 5 10280 5 10278 5 10273 0 10271 5 10256 0 100 0 $ 10335.0 10331.0 10328.5 10317.5 10311.5 10301.5 10296.5 10286.5 10281.5 10278.5 10271.0 98.0 10329.0 10317.0 10303.0 10285.0 10277.0 10270.5 10256.5 100.5 REMARKS: THIS FILE CONTAINS TDTP BASELINE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT BASELINE PASS #2 GRCH TO BASELINE PASS #1 GRCH, AND BASELINE PASS #2 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 13 ** SET TYPE - CHAN ** NA~E 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 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SBHFTDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TSCFTDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12174. 000 SIGM. TDTP 11. 418 TPHI. TDTP 21. 231 SBHF. TDTP 31. 311 SBHN. TDTP 43 . 895 SIGC. TDTP O. 928 SIBH. TDTP 54 . 918 TRAT. TDTP 1 . 833 SDSI.TDTP 0.141 BACK. TDTP 214.831 FBAC. TDTP 50.376 TCAN. TDTP 111546.984 TCAF. TDTP 48280.266 TCND.TDTP 31552.031 TCFD. TDTP 11093.031 TSCN. TDTP 12464.191 TSCF. TDTP 5394. 808 INND. TDTP 860. 1 62 INFD. TDTP 350. 174 GRCH. TDTP -999. 250 T~NS. TDTP -70. 000 CCL. TDTP O. 000 DEPT. 10244. 000 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP - 999. 250 TCAN. TDTP - 999. 250 TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 26.734 TENS. TDTP -999. 250 CCL. TDTP -999. 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 14 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION · O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NTJMBER : 3 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12147.0 10246.0 TDTP 12176.0 10246.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.0 88888.0 88887.0 12155.0 12154.0 12149.0 12147.5 12126.0 12125.5 12096.0 12095.5 12087.5 12087.5 12071.0 12071.0 12065.5 12065.0 12058.5 12058.0 12057.0 12055.5 12050.5 12048.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12049.5 12048.5 12044.5 12043.5 12040.0 12039.5 12030.0 12028.5 12001.0 12000.5 12000.5 11986.0 11985.5 11976.5 11976.5 11978.5 11966.5 11966.5 11960.5 11961.0 11951.5 11952.5 11938.5 11941.5 11926.0 11928.5 11917.0 11916.5 11913.0 11912.5 11911.5 11910.0 11907.5 11906.5 11898.0 11897.5 11885.0 11884.0 11865.5 11865.0 11861.5 11861.0 11860.5 11859.5 11855.5 11855.0 11853.0 11853.0 11848.5 11848.0 11832.0 11832.0 11824.0 11823.5 11797.5 11797.0 11792.0 11791.0 11776.5 11775.5 11700.5 11700.0 11691.0 11690.0 11675.0 11674.5 11631.0 11631.0 11606.5 11605.5 11595.5 11595.0 11577.0 11576.5 11566.0 11567.0 11557.0 11559.0 11552.5 11551.5 11545.0 11545.0 11524.5 11524.5 11503.0 11502.5 11482.5 11481.5 11461.5 11461.0 11450.5 11449.5 11427.5 11426.0 11417.0 11416.0 11408.0 11406.5 11404.0 11403.0 11394.0 11393.0 11374.5 11373.5 11373.5 11372.5 11359.0 11356.5 11358.5 11357.5 11334.5 11333.5 14-APR-1997 13:35 PAGE: 15 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11333.5 11330.0 11292.5 11281.0 11249.0 11243.0 11237.0 11195.0 11157.5 11096.5 11096.0 11044 5 11025 0 11009 5 10996 5 10986 5 10977 5 10966.0 10934.5 10905.0 10888.5 10864.0 10835.0 10819.0 10808.0 10806.5 10796.5 10777.0 10775.5 10762.5 10760.5 10744.5 10743.5 10739.0 10738.5 10733.0 10731.5 10719.5 10716.5 10710.0 10699.5 10697.5 10692.0 10691.5 10660.5 10660.0 10644 5 10631 5 10631 0 10616 5 10602 0 10594 0 10593 5 10587 5 10582, 0 11331.5 11291.0 11240.0 11155.0 11095.5 11043.5 11009.5 10985.5 10965.5 10933.0 10902.5 10886.5 10863.5 10819.0 10807.5 10794.5 10776.0 10759.5 10743.0 10738.5 10730.5 10709.5 10695.5 10690.5 10659.5 10629.5 10600.5 10592.5 10586.5 10581.0 11329.0 11280.5 11248.0 11236.5 11194.0 11095.5 11026.0 10996.5 10978.0 10834.0 10807.0 10776.0 10759.5 10742.5 10738.5 10732.5 10719.0 10715.5 10698.5 10690.5 10659.5 10645.0 10629.5 10616.5 10601.5 10592.5 14-APR-1997 13:35 PAGE: 16 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 10581.0 10568.5 10567.5 10559.0 10545.0 10531.5 10523.5 10498.5 10490.5 10486.5 10485.5 10478 0 10463 0 10453 5 10448 5 10448 0 10425 0 10424 0 10400 0 10393.0 10385.5 10384.0 10381.0 10378.5 10375.5 10372.5 10371.0 10367.5 10362.5 10352.5 10346.0 10339.5 10337.5 10336.5 10332.5 10331.5 10329.5 10329.0 10327.5 10321.5 10318.5 10312.5 10311.5 10304.0 10303.5 10294.0 10289.0 10276.0 10272.5 10271.5 10257.0 100.0 $ 10566.0 10521.5 10488.5 10484.5 10451.5 10446.5 10423.5 10392.0 10384.0 10379.5 10374.0 10369.5 10361.0 10344.5 10337.5 10335.0 10331.0 10328.0 10326.0 10320.0 10317.0 10311.0 10302.5 10287.5 10271.0 98.5 10581.0 10566.0 10556.0 10541.5 10529.0 10496.5 10484.0 10476.0 10461.0 10451.5 10446.5 10423.5 10399.0 10383.0 10378.0 10371.5 10367.0 10351.5 10337.0 10331.0 10328.5 10310.5 10302.5 10293.0 10275.0 10270.5 10256.5 99.5 PAGE: 17 REMARKS: THIS FILE CONTAINS THE TDTP BORAX PASS #1. THE DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 18 SHIFTS SHOWN ABOVE REFLECT BORAX PASS #1 GRCH TO BASELINE PASS #1 GRCH, AND BORAXPASS #1SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 505980 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 19 NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CUSS MOD NUMB SAMP ELEM CODE (HEX) TSCN TDTP CPS 505980 TSCF TDTP CPS 505980 INND TDTP CPS 505980 INFD TDTP CPS 505980 GRCH TDTP GAPI 505980 TENS TDTP LB 505980 CCL TDTP V 505980 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12175. 000 SIGM. TDTP 13 . 170 TPHI. TDTP 27. 246 SBHF. TDTP 40. 1 09 SBHN. TDTP 62. 457 SIGC. TDTP O. 306 SIBH. TDTP 110. 437 TRAT. TDTP 1 . 957 SDSI. TDTP O. 164 BACK. TDTP 25. 049 FBAC. TDTP 11 . 877 TCAN. TDTP 57479. 633 TCAF. TDTP 23490. 492 TCND. TDTP 27894 . 379 TCFD. TDTP 9644 . 225 TSCN. TDTP 11345. 592 TSCF. TDTP 4636.660 INND. TDTP 843.811 INFD. TDTP 378.082 GRCH. TDTP -999.250 TENS. TDTP -70. 000 CCL. TDTP O. 000 DEPT. 10244. 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP -999. 250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 25.188 TENS. TDTP -999. 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 2O FILE HEADER FILE AUJM~ER .. 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SUM~3kRY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12154.0 10248.0 TDTP 12183.0 10248.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12103.0 12090.5 12082.5 12071.0 12066.0 12060 5 12050 5 12047 5 12040 5 12015 0 12001 0 11988.0 11958.0 11944.5 11938.0 11923.0 11908.0 11898.0 11866.0 11863.0 11861.0 11859.5 11853.5 11846.5 11832.0 11822.0 11815.5 11797.5 11790.5 11776.5 11755.0 11742.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.5 12102.5 12088.0 12081.5 12071.0 12058 0 12048 5 12045 0 12039 5 12014 5 12000 5 119880 11922.0 11864.5 11862.0 11859.5 11847.0 11815.5 11791.0 11743.5 88887.0 12065.0 11958.5 11946.0 11941.0 11906.5 11897.5 11857.5 11853.0 11832.0 11821.5 11797.0 11775.5 11754.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11722.5 11694.0 11692.0 11677.5 11640.5 11617.5 11608.0 11591.5 11580.5 11572.0 11557.5 11545.5 11538.5 11526.0 11519.0 11497.5 11483.5 11450.5 11426.0 11394.0 11374.0 11373.5 11358.5 11334.5 11330.0 11324.0 11302.0 11283.0 11282.5 11249.0 11238.0 11216.5 11177 5 11170 5 11161 5 11127 5 11096 5 11080 5 11067 0 11025 0 11012 5 10995.5 10978.0 10967.0 10941.5 10925.0 10889.0 10835.5 10832.0 10819.5 10815.0 10807.5 10807.0 10797.0 10785.0 11724.5 11694.5 11678.0 11607.5 11524.5 11426.5 11373.0 11329.0 11281.0 11169.5 11095.5 11065.5 11011.5 10965.5 10923.0 10886.5 10831.5 10819.0 10814.0 10807.5 10783.5 14-APR-1997 13:35 11690.5 11639.0 11617.0 11590.5 11580.5 11573.0 11559.0 11545.5 11537.5 11520.0 11496.5 11482.0 11449.5 11393.0 11373.0 11356.5 11333.5 11329.0 11323.5 11301.5 11283.0 11247.5 11237.5 11215.5 11176.5 11159.5 11127.0 11095.5 11079.5 11026.0 10996.0 10977.5 10940.5 10834.0 10807.5 10797.0 PAGE: 21 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10777.5 10775.0 10761.0 10760.5 10744 5 10743 5 10739 5 10738 5 10735 0 10733 0 10732 0 10720.5 10710.5 10709.5 10699.0 10697.5 10692.0 10691.5 10661.0 10660.0 10648.0 10646.5 10644.5 10640.0 10631.5 10630.5 10602.5 10594.0 10593.5 10588.0 10580.5 10578.5 10568.5 10560.0 10559.0 10544.5 10536.0 10524.5 10523.5 10510.5 10500.5 10493.0 10486.5 10485.5 10478.0 10465.0 10463.0 10454.0 10453.0 10451.5 10448.5 10448.0 10441.0 10433.0 10428.0 10776.0 10760.0 10743.0 10738.0 10734.0 10730.5 10709.5 10696.0 10690.5 10659.5 10645.0 10629.5 10600.5 10592.5 10586.5 10577.0 10566.0 10558.0 10521.5 10491.0 10484.5 10463.5 10452.0 10448.5 10446.5 10776.5 10759.5 10743.0 10738.5 10732.5 10720.5 10708.5 10698.5 10690.5 10659.5 10648.0 10644.5 10640.0 10629.5 10601.5 10592.5 10580.5 10566.0 10556.0 10542.0 10534.0 10522.0 10508.5 10499.0 10484.0 10476.5 10460.5 10451.5 10446.5 10440.0 10432.0 10427.0 14-APR-1997 13:35 PACE: 22 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 23 10425.5 10423.5 10424.5 10423.5 10420.0 10420.0 10407.0 10406.0 10403.0 10400.5 10391.0 10390.0 10386.0 10384.0 10384.0 10382.0 10383.0 10381.0 10379.5 10379.0 10378.0 10375.5 10373.5 10374.5 10373.0 10371.5 10368.5 10366.5 10359.5 10357.5 10356.5 10355.0 10352.0 10351.5 10347.5 10346.5 10343.0 10342.0 10339.5 10337.5 10336.5 10335.0 10332.5 10331.0 10332.0 10331.0 10330.0 10328.0 10321.5 10320.0 10319.0 10317.5 10316.5 10315.0 10313.0 10311.5 10312.0 10311.0 10304.5 10302.5 10303.5 10302.5 10294.5 10293 . 0 10288.5 10287.5 10287.0 10286.0 10276.5 10275.0 10275.5 10274.0 10272.5 10270.5 10271 . 5 10270.5 10264.5 10263.5 100.0 99.0 99.0 $ REMARKS: THIS FILE CONTAINS TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT BORAX PASS #2 GRCH TO BASELINE PASS #1 GRCH, AND BORAX PASS #2 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNTDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 25 ** DATA ** DEPT. 12182. 000 SIGM. TDTP 13. 379 TPHI. TDTP SBPZN. TDTP 65.538 SIGC. TDTP O. 136 SIBH. TDTP SDSI. TDTP O. 211 BACK. TDTP 144. 215 FBAC. TDTP TCAF. TDTP 18704.289 TCND. TDTP 27764.574 TCFD. TDTP TSCF. TDTP 4730.706 INND. TDTP 938. 294 INFD. TDTP TENS. TDTP -70. 000 CCL. TDTP O. 000 26.475 117.910 47.059 9841.211 350.287 SBHF. TDTP TRA T. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP 43.175 1.914 44919. 844 11361. 170 -999.250 DEPT. 10247. 000 SIGM. TDTP 18. 430 TPHI. TDTP 20. 600 SBHF. TDTP 63. 853 SBPZN. TDTP 77. 485 SIGC. TDTP O. 298 SIBH. TDTP 140. 905 TRAT. TDTP 1 . 484 SDSI.TDTP 0.367 BACK. TDTP 233.906 FBAC. TDTP 48.179 TCAN. TDTP 21617.625 TCAF. TDTP 10937. 943 TCND. TDTP 17217. 699 TCFD. TDTP 6674 . 519 TSCN. TDTP 4809. 896 TSCF. TDTP 2433 . 679 INND. TDTP 858. 304 INFD. TDTP 375. 694 GRCH. TDTP 25. 828 TENS. TDTP -70. 000 CCL. TDTP O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION : O01CO1 DATE . 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUM~ER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 12153.0 TDTP 12182.0 STOP DEPTH 10254.0 10254.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 26 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12109.0 12108.0 12097.0 12081.0 12071.5 12067.0 12057.0 12054.5 12044.5 12040.5 12024 5 12015 5 11994 5 11969 5 11959 5 11945,0 11933.5 11924.0 11912.0 11908.0 11904.0 11902.5 11898.5 11864.5 11859.0 11858.0 11856.0 11848.0 11822.0 11805.0 11798.5 11776.5 11683.5 11678.5 11677.0 11628.5 11625.5 11617.0 11599.5 11592.5 11580.0 11578.5 11570.0 11557.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88886.5 88887.5 12107.5 12071.0 12056.0 12039.5 12024.0 12014.5 11994.0 11969.5 11903.0 11864.5 11859.0 11855.0 11847.0 11683.5 11678.5 11629.0 11579.0 12107.5 12095.0 12079.5 12065.0 12052.5 12043.5 11959.0 11947.0 11935.5 11925.5 11910.0 11906.5 11902.5 11898.0 11857.0 11821.0 11805.0 11797.5 11776.0 11675.0 11624.5 11615.5 11598.0 11590.5 11580.5 11570.5 11559.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 27 11546.5 11525.0 11498.5 11495.0 11451.0 11435.5 11423.5 11416.5 11408.5 11395.0 11375.5 11359 5 11337 5 11334 5 11331 0 11330 5 11325 0 11300.0 11275.0 11251.0 11249.0 11238.5 11224.0 11215.5 11196.5 11195.5 11179.0 11119.0 11097.0 11091.0 11044.0 11026.0 10996.5 1 O988.5 10985.0 10984.5 10978.5 10967.0 10959.5 10931.5 10917.5 10888.5 10882.5 10843.0 10836.0 10832.5 10820.0 10816.0 10809.5 10807.5 10789.0 10783.0 10778.5 10776.0 10760.5 11524.5 11498.0 11424.5 11336.0 11329.5 11275.0 11250.5 11196.5 11090.5 11043.0 10984.0 10965.5 10931.5 10886.5 10841.5 10831.5 10819.0 10814.0 10809.0 10786.5 10776.0 10759.5 11545.5 11493.5 11449.5 11434.0 11415.5 11407.0 11393.0 11373.0 11357.0 11333.5 11329.0 11323.5 11299.0 11247.5 11237.0 11222.5 11215.0 11194.0 11176.5 11117.0 11095.5 11026.0 10996.5 10988.0 10984.0 10978.0 10958.0 10914.5 10880.5 10834.5 10807.5 10783.5 10776.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 28 10760.0 10745.5 10745.0 10740.5 10740.0 10735.0 10734.0 10732.5 10720.5 10712.0 10710.0 10700.0 10692.5 10692.0 10683.5 10661.0 10656.0 10652.5 10647.5 10641.0 10636.0 10632.5 10631.5 10603.0 10594.5 10583.5 10582.0 10569.5 10568.5 10559.0 10556.0 10544.5 10531.5 10524.5 10487.5 10486.5 10468.5 10466.0 10463.5 10454.5 10454 0 10449 5 10449 0 10441 0 10433 5 10425 5 10425 0 10392 0 10386.5 10384.5 10382.0 10379.5 10378.0 10376.0 10374.0 10742.5 10738.0 10733.5 10730.5 10709.5 10690.5 10645.0 10629.5 10600.5 10592.5 10581.0 10566.0 10522.0 10484.5 10463.5 10451.5 10446.5 10423.5 10384.5 10382.0 10379.5 10375.5 10373.5 10759.0 10743.0 10738.5 10732.5 10719.5 10708.5 10698.5 10690.5 10681.5 10660.0 10654.5 10652.0 10640.0 10634.5 10629.5 10601.5 10592.5 10581.0 10566. 0 10556.0 10552.0 10541.5 10528.5 10521.5 10484.5 10465.5 10460.5 10451.5 10446.5 10440.0 10432.5 10423.5 10390.0 10383.0 10378.0 10371.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 29 10371 . 5 10369.5 10362.5 10360 5 10352.5 10351.5 10346.0 10344.0 10340.0 10337.5 10338.0 10336.5 10336.5 10334.5 10333.0 10331.0 10332.5 10331.0 10330.5 10328.5 10328.5 10326.5 10322.5 10320.0 10319.5 10317.5 10315.5 10315.0 10313.0 10311.0 10312.0 10310.5 10302.0 10300.0 10297.0 10295.5 10294.5 10293.0 10289.5 10287.5 10280.0 10277.5 10276.5 10274.5 10273.0 10271.0 10272.0 10270.5 10264.0 10263.5 100.0 99.5 98.5 $ REMARKS: THIS FILE CONTAINS TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #3 GRCH TO BASELINE PASS #1 GRCH, AND BORAX PASS #3 SIGM TO BASELINE PASS #1 SIGM. ALLOTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 3O TYPE REPR CODE VALUE 11 66 11 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 APIAPI API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TSCNTDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 GRCHTDTP GAPI 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12181.500 SIGM. TDTP 13.490 TPHI.TDTP 23.907 SBHF. TDTP SBHN. TDTP 63.995 SIGC. TDTP 0.110 SIBH. TDTP 110.474 TRAT. TDTP SDSI.TDTP 0.224 BACK. TDTP 207.392 FBAC. TDTP 47.389 TCAN. TDTP TCAF. TDTP 33472.250 TCND.TDTP 26767.930 TCFD.TDTP 10213.988 TSCN. TDTP TSCF. TDTP 5003.479 INND. TDTP 798.887 INFD.TDTP 285.027 GRCH. TDTP TENS.TDTP -70.000 CCL.TDTP 0.000 DEPT. 10252.500 SIGM. TDTP 19. 988 TPHI. TDTP 19.257 SBHF. TDTP SBHN. TDTP 79. 546 SIGC. TDTP O. 242 SIBH. TDTP 144 . 059 TRAT. TDTP SDSI. TDTP O. 480 BACK. TDTP 265. 442 FBAC. TDTP 55. 421 TCAN. TDTP TCAF. TDTP 9284. 008 TCND. TDTP 16266. 111 TCFD. TDTP 6320. 362 TSCN. TDTP 50.846 1.808 74765.969 11176.125 -999.250 66.071 1.382 17718.559 4015.238 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 31 TSCF. TDTP 2103 . 868 INND. TDTP TENS. TDTP -70. 000 CCL. TDTP 895.453 INFD.TDTP 0.000 376.318 GRCH. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUNmlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12148.0 10250.0 TDTP 12177.0 10250.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88886.0 88888.0 12130.0 12128.0 12122.5 12121.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 32 12107.5 12104.0 12098.0 12093.0 12090.5 12081.0 12072.0 12067.0 12051.0 12041.5 12027.0 12009.0 11996.5 11989.0 11972.0 11968.0 11958.0 11952.5 11938.0 11934.0 11917.5 11908.5 11900.0 11899.5 11866.5 11861.0 11853.5 11849.5 11834.5 11822.5 11812.5 11798.5 11792.0 11776.5 11773.5 11766.5 11759.5 11737 0 11701 0 11685 0 11679 5 11676 0 11672 5 11629 5 11617.5 11608.0 11599.5 11596.0 11593.0 11581.0 11571.0 11559.0 11546.0 11524.0 11523.5 12102.5 12092.0 12088.0 12071.0 12048.5 12039.0 12025.5 12007.0 11994.0 11988.0 11972.0 11898.5 11864.5 11859.5 11848.0 11835.0 11812.0 11772.5 11758.0 11736.5 11683.5 11678.5 11524.5 12107.5 12095.0 12080.0 12065.0 11967.0 11958.0 11953.0 11941.0 11935.5 11916.5 11906.5 11898.0 11853.0 11821.5 11797.5 11791.0 11775.5 11766.0 11700.0 11674.5 11670 5 11627 5 11616 5 11607 5 11597 5 11594 5 11590 5 11580 5 11570.5 11559.5 11545.5 11522.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 33 11463 0 11451 5 11427 0 11421 0 11409 0 11394 5 11359 0 11338 5 11337 5 11330 0 11324.5 11302.5 11296.0 11282.0 11279.0 11272.0 11249.5 11239.5 11239.0 11224.0 11210.0 11196.0 11178.5 11175.0 11161.5 11135.5 11097.0 11026.0 10996.5 10978.0 10958.5 10888.5 10884.0 10882.0 10865.0 10843.0 10836.0 10833.0 10820.0 10815.5 10808.0 10807.0 10788.5 10777.0 10776.0 10761.0 10744.5 10739 5 10734 5 10733 5 10732 0 10715 5 10711 0 10705.5 10698.0 11465.0 11425.0 11340.0 11281.0 11240.5 11208.0 11174.0 11095.0 10886.5 10882.0 10834.0 10819.5 10814.0 10808.0 10786.5 10774.0 10742.5 10738.0 10733.5 10730.5 10709.5 10696.0 11449.5 11426.5 11407.0 11393.0 11357.0 11337.0 11329.0 11323.5 11301.5 11295.5 11280.5 11270.5 11247.5 11237.0 11222.5 11194.0 11177.0 11159.5 11134.0 11095.5 11026.0 10996.5 10977.5 10958.0 10880.5 10863.5 10841.5 10834.5 10807.0 10776.5 10759.5 10743.0 10739.0 10732.5 10715.0 10704.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 34 10696.5 10695.5 10692.0 10690.5 10690.5 10661 . 0 10659.0 10660.0 10659.5 10648.5 10648.0 10645.0 10645.0 10634.0 10632.5 10632.0 10629.5 10594.5 10592.5 10594.0 10592.5 10583.0 10581.0 10582.0 10581 . 0 10569.5 10566.0 10568.0 10566.0 10559.0 10556.0 10544.5 10541.0 10528.5 10525.5 10524.5 10521.5 10524.0 10521.5 10511.5 10508.5 10498.5 10496.5 10491.0 10488.5 10487.0 10484.5 10486.5 10484.5 10468.5 10465.5 10463 . 5 10460.5 10454.0 10452.0 10453 . 5 10451 . 5 10452.0 10449.0 10449.0 10446.5 10441 . 0 10440.0 10435.0 10433.0 10433 . 5 10432.5 10427.5 10426.5 10425.5 10423.5 10424.5 10423.0 10391.0 10390.0 10386.0 10384.0 10384.5 10383.5 10381.5 10379.5 10379.0 10378.0 10376.0 10374 . 0 10374 . 5 10373.0 10372.0 10369.5 10368.5 10364.0 10363.0 10360.0 10358.0 10353.0 10352.0 10346.0 10344.0 10340.0 10337.5 10338.5 10337.0 10337.0 10335.0 10333.0 10331.0 10332.5 10331.0 10330.0 10328.0 10325.5 10323.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 35 10319.5 10317.5 10313.0 10311.5 10312.0 10310.5 10310.0 10308.0 10307.0 10306.5 10304.5 10302.5 10304.0 10302.5 10296.5 10296.0 10294.5 10293.0 10291.0 10289.0 10277.5 10276.0 10276.5 10274.5 10273.0 10271.0 10272.0 10270.5 100.0 98.0 98.5 $ REMARKS: THIS FILE CONTAINS BORAX PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #4 GRCH TO BASELINE PASS #1 GRCH, AND BORAX PASS #4 SIGM TO BASELINE PASS #1 SIGM. ALLOTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 36 ** 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 505980 O0 000 SIGMTDTP CU 505980 O0 000 TPHI TDTP PU-S 505980 O0 000 SBHF TDTP CU 505980 O0 000 SBHN TDTP CU 505980 O0 000 SIGC TDTP CU 505980 O0 000 SIBH TDTP CU 505980 O0 000 TRAT TDTP 505980 O0 000 SDSI TDTP CU 505980 O0 000 BACK TDTP CPS 505980 O0 000 FBAC TDTP CPS 505980 O0 000 TCAN TDTP CPS 505980 O0 000 TCAF TDTP CPS 505980 O0 000 TCND TDTP CPS 505980 O0 000 TCFD TDTP CPS 505980 O0 000 TSCNTDTP CPS 505980 O0 000 TSCF TDTP CPS 505980 O0 000 INND TDTP CPS 505980 O0 000 INFD TDTP CPS 505980 O0 000 GRCH TDTP GAPI 505980 O0 000 TENS TDTP LB 505980 O0 000 CCL TDTP V 505980 O0 000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 6~ 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12177.000 SIGM. TDTP 12.277 TPHI.TDTP 22.947 SBHF. TDTP SBHN. TDTP 60.926 SIGC. TDTP 0.527 SIBH. TDTP 101.113 TRAT. TDTP SDSI.TDTP 0.176 BACK. TDTP 149.001 FBAC. TDTP 29.393 TCAN. TDTP TCAF. TDTP 18502.293 TCND.TDTP 26140.836 TCFD.TDTP 9390.807 TSCN. TDTP TSCF. TDTP 4666.404 INND. TDTP 805.053 INFD.TDTP 338.144 GRCH. TDTP TENS.TDTP -70.000 CCL.TDTP 0.000 DEPT. 10248.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD.TDTP -999.250 GRCH. TDTP TENS. TDTP -999.250 CCL.TDTP -999.250 46.508 1.823 41981.625 10588.051 -999.250 -999.250 -999.250 -999.250 -999.250 28. 563 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 37 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION ' O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 EILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 7 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 7 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12147.0 10245.0 TDTP 12167.0 10245.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12151.0 12130.5 12127.5 12109.0 12096.0 12095.0 12084.0 12080.0 12071.0 12066.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88885.0 88887.5 12127.5 12107.0 12094.0 12081.5 12071.0 12150.5 12125.5 12095.5 12079.5 12065.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 38 12049.5 12048.5 12045.5 12045.0 12040.5 12039.5 12022.5 12024.0 12018.0 12018.0 12014.0 12014.5 12004.5 12004.5 12002.0 12000.5 11978.5 11978.5 11969.0 11970.0 11957.5 11958.5 11938.0 11941.0 11916.5 11916.5 11911.5 11910.0 11907.5 11906.5 11898.5 11897.5 11878.0 11879.5 11864.5 11864.5 11855.5 11855.0 11854.0 11854.0 11831.5 11831.5 11824.5 11823.5 11797.5 11797.0 11775.0 11775.0 11759.5 11758.5 11752.0 11754.0 11684.5 11683.5 11680.0 11678.0 11678.5 11678.0 11650.5 11649.0 11617.5 11617.0 11605.5 11605.5 11598.0 11597.5 11594.5 11594.5 11592.0 11590.5 11580.0 11580.5 11566.0 11567.5 11558.0 11559.0 11555.5 11555.0 11546.5 11545.5 11523.5 11523.0 11509.5 11509.5 11482.5 11481.0 11464.0 11465.5 11450.5 11449.5 11439.5 11441.0 11434.5 11434.0 11394.5 11393.0 11378.0 11377.5 11333.0 11331.0 11331.0 11330.0 11329.5 11329.0 11328.0 11326.0 11325.0 11323.5 11296.0 11294.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 39 11248.5 11247.5 11237.5 11237.0 11216.5 11215.5 11195.0 11194.0 11159.0 11156.5 11097.0 11095.5 11096.0 11095.5 11045.5 11043.5 11028.0 11028.0 10996.0 10996.5 10888.0 10886.0 10874.0 10873.0 10842.5 10842.0 10835.0 10834.5 10819.0 10819.0 10818.5 10818.5 10808.0 10807.5 10806.0 10807.0 10781.5 10782.5 10777.0 10775.5 10772.5 10772.5 10759.5 10758.5 10743.5 10743.0 10742.5 10739.0 10738.5 10738.0 10738.5 10734.0 10733.5 10733.0 10732.5 10732.5 10730.5 10711.0 10709.5 10709.5 10709.0 10697.5 10696.0 10696.0 10695.5 10692.0 10690.5 10691.5 10691.0 10660.5 10659.5 10660.0 10659.5 10651.5 10651.5 10646.0 10644.5 10644.0 10644.5 10640.0 10640.0 10631.5 10629.5 10630.0 10629.5 10602.5 10601.5 10594.0 10592.5 10593.5 10592.5 10589.5 10588.0 10581.5 10581.0 10581.0 10581.0 10568.5 10566.5 10567.5 10566.0 10563.0 10559.5 10559.0 10556.0 10544.0 10541.5 10531.0 10528.5 10524.5 10522.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 4O 10523.5 10521.5 10510.5 10508.5 10500.5 10499.0 10490.5 10488.5 10486.5 10484.5 10485.5 10484.0 10468.0 10465.5 10463.0 10460.5 10453.5 10451.5 10453.0 10451.5 10448.5 10446.5 10425.0 10423.5 10424.0 10423.5 10390.5 10390.0 10385.5 10384.0 10384.0 10383.0 10381.0 10379.5 10378.5 10378.0 10375.5 10373.5 10372.5 10371.5 10370.5 10370.0 10367.5 10367.0 10362.0 10361.0 10352.5 10351.5 10346.5 10345.5 10338.0 10337.0 10336.0 10334.5 10332.5 10331.0 10332.0 10331.0 10318.5 10317.0 10312.5 10311.0 10312.0 10311.0 10304.0 10302.5 10303.0 10294.0 10293.0 10288.5 10287.5 10275.5 10275.0 10272.5 10271.0 10271.5 10270.5 10260.0 10259.0 100.0 98.5 99.0 $ REMARKS: THIS FILE CONTAINS THE TDTP FLUSHED PASS. THE DEPTH SHIFTS SHOWN ABOVEREFLECT FLUSHED PASS GRCH TO BASE- LINE PASS #1 GRCH, AND FLUSHED PASS SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNTDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TSCNTDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 7 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 42 ** DATA ** DEPT. 12166.500 SIGM. TDTP 16. 205 TPHI. TDTP 28. 821 SBHF. TDTP 42. 275 SBHN. TDTP 43. 550 SIGC. TDTP O. 000 SIBH. TDTP 56. 388 TRAT. TDTP 1. 950 SDSI. TDTP O. 348 BACK. TDTP 198. 216 FBAC. TDTP 38. 938 TCAN. TDTP 46129. 500 TCAF. TDTP 18344. 855 TCND. TDTP 26306. 551 TCFD. TDTP 8576. 979 TSCN. TDTP 9510. 936 TSCF. TDTP 3782.324 INND. TDTP 842.993 INFD. TDTP 298.530 GRCH. TDTP -999.250 TENS. TDTP -70. 000 CCL. TDTP O. 000 DEPT. 10243. 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP 36. 719 TENS. TDTP -999. 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE · 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 8 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 8 DEPTH INCREMENT: O . 5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH GRCH 12148.0 TDTP 12177.0 STOP DEPTH 10244.0 10244.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 43 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12174.0 12152.5 12141.5 12133 0 12117 0 12104 0 12100 0 12098 5 12096 0 12080.5 12071.0 12066.0 12052.5 12049.5 12045.0 12040.5 12021.0 12008.5 12000.5 11995.0 11987.5 11979.0 11969.5 11966.0 11958.0 11956.5 11951.0 11937.5 11926.5 11916.5 11911.5 11911.0 11898.0 11882.5 11864.0 11862.0 11860.0 11855.5 11853.0 11838.0 11824.0 11821.0 11815.5 11811.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88889.0 88887.5 12173.5 12152.0 12142.5 12105.5 12097.5 12071.0 12048.5 12039.5 12007.0 11994.0 11988.0 11971.0 11959.0 11950.0 11912.5 11865.0 11862.0 11855.0 11823.5 11812.0 12133.0 12118.5 12100.0 12095.0 12080.0 12065.0 12052.0 12044.0 12020.5 12000.0 11979.0 11965.5 11959.0 11951.5 11941.0 11928.0 11916.0 11910.0 11897.5 11882.0 11860.0 11853.0 11838.0 11821.0 11815.5 11811.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 44 11797.5 11790.5 11786.5 11775.0 11770.0 11754.5 11691.0 11684 5 11679 0 11675 5 11667 0 11649 0 11626 0 11599 5 11595 0 11594.5 11579.5 11560.5 11558.5 11545.5 11537.5 11497.5 11495.5 11482.0 11450.5 11440.5 11426.5 11407.0 11402.0 11394.0 11374.0 11330.0 11329.5 11323.5 11299.5 11291.0 11280.5 11248.5 11238.5 11224.5 11208.5 11206.5 11196.0 11161.0 11128.0 11120.0 11096.5 11066.5 11047.5 10996.0 10988.0 10964.5 10935.0 10903.5 10888.0 11683.5 11678.0 11595.0 11557.5 11534.5 11493.5 11441.0 11403.0 11329.5 11291.0 11208.0 11120.0 11095.5 11065.5 10985.5 10963.0 10933.0 10886.0 11797.5 11791.0 11784.5 11776.0 11768.5 11754.0 11690.5 11674.0 11666.5 11648.5 11624.5 11598.5 11595.0 11580.5 11559.0 11545.0 11497.0 11481.5 11449.5 11425.5 11406.5 11393.0 11372.5 11329.5 11323.5 11299.0 11280.0 11247.5 11237.0 11222.5 11206.0 11194.5 11159.0 11127.0 11096.0 11047.0 10996.5 10905.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 45 10882.5 10881.0 10869.0 10854.0 10849 5 10841 5 10836 0 10835 5 10827 5 10815 5 10808 0 10807 5 10782 0 10777 5 10761 0 10744 5 10744 0 10740.0 10739.5 10734.0 10733.0 10731.5 10720.5 10711.0 10709.5 10699.5 10697.5 10692.0 10661.0 10660.5 10652.5 10645.0 10640.5 10636.0 10631.5 10631.0 10618.0 10602.5 10594.5 10594.0 10583.0 10581.5 10568.5 10568 0 10559 0 10545 0 10537 5 10528 5 10524 0 10516 0 10511, 0 10491.0 10487.0 10486.5 10467.5 10881.5 10867.5 10854.0 10841.5 10834.5 10826.5 10814.0 10807.5 10776.0 10742.5 10738.5 10733.0 10730.5 10709.0 10696.0 10690.5 10659.5 10629.5 10592.5 10581.0 10566.0 10521.5 10488.5 10484.5 10880.5 10847.5 10834.5 10807.5 10783.0 10759.5 10742.5 10738.5 10732.0 10719.5 10708.5 10698.5 10691.0 10659.5 10652.0 10645.0 10640.0 10635.0 10630.0 10616.0 10601.5 10592.5 10581.0 10566.0 10556.0 10541.5 10534.0 10525.5 10513.5 10508.0 10484.5 10465.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 46 10463.5 10460.5 10459.0 10457.0 10453.5 10451.5 10451.5 10449.0 10446.5 10448.0 10446.5 10441.0 10439.5 10433.5. 10432.5 10428.0 10427.0 10425.0 10423.5 10424.5 10423.5 10402.5 10400.5 10391.5 10390.0 10386.5 10384.0 10384.5 10383.0 10381.0 10379.5 10379.0 10378.0 10375.5 10373.5 10374.5 10373 . 0 10371 . 5 10367.5 10367.0 10362.5 10361.0 10352.5 10351.5 10346.0 10344.0 10338.0 10336.5 10336.5 10334.5 10332.5 10331.0 10332.0 10330.5 10330.0 10328.0 10322.0 10320.5 10319.0 10317.0 10313.0 10311.0 10312.0 10310.5 10304.0 10302.5 10303.0 10294.5 10293.5 10290.5 10289.0 10276.5 10275.0 10272.5 10270.5 10272.0 10270.5 10258.0 10256.5 100.0 98.0 98.5 $ REMARKS: THIS FILE CONTAINS THE TDTP FLOWING PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT FLOWING PASS GRCH TO BASE- LINE PASS #1 GRCH, AND FLOWING PASS SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 47 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SBP~N TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 CRCH TDTP GAPI 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 8 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 48 ** DATA ** DEPT. 12176. 500 SIGM. TDTP 12. 672 TPHI. TDTP 25. 307 SBHF. TDTP 37. 457 SBHN. TDTP 52.157 SIGC. TDTP O. 418 SIBH. TDTP 79. 260 TRAT. TDTP 1. 930 SDSI. TDTP O. 167 BACK. TDTP 38. 276 FBAC. TDTP 12. 900 TCAN. TDTP 62693 . 375 TCAF. TDTP 25782. 965 TCND. TDTP 33214. 406 TCFD. TDTP 11532. 658 TSCN. TDTP 13295. 902 TSCF. TDTP 5468.007 INND. TDTP 841.413 INFD. TDTP 412.356 GRCH. TDTP -999.250 TENS. TDTP -70. 000 CCL. TDTP O. 000 DEPT. 10242. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 - 999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 TCAN. TDTP -999. 250 TSCN. TDTP - 999. 250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 21.953 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE · 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 9 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1, 2, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 REMARKS: THE ARITHMETIC AVERAGE OF THE BASELINE PASSES (l&2) WAS CALCULATED AFTER CLIPPING ANDDEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA PAGE: 49 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 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 ELE~ CODE (HEX) DEPT FT 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000' TPHI PNAV PU-S 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SBHNPNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PNAV 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TCAN PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 5O NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TSCF PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 INND PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 12181.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 83.983 FBAC. TDTP 26.418 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP -999.250 DEPT. 10234.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP 57.844 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION . O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE . FLIC VERSION · O01CO1 DATE . 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES 10 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 51 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUNk¢ARY VEiVDOR TOOL CODE START DEPTH TDTP 12190.0 $ LOG HEADER DATA STOP DEPTH 10232.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 6-FEB-97 CP 42.2 1412 5-FEB-97 12180.0 12182.0 10250.0 12180.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ TOOL NUMBER TArD 230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 52 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COtrNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BASELINE PASS #1. $ LIS FORMAT DATA ** DATA FO~T SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 53 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CUSS MOD NUMB SAMP ELEM CODE (HEX) TPHI PS1 PU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SBP~NPS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS1 505980 O0 000 O0 0 10 1 1 4 68 0000000000 ~OF PS1 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PSi CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS1 LB 505980 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS1 GAPI 505980 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS1 V 505980 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 12190.000 SIGM. PS1 19.154 TPHI.PS1 14.342 SBHF. PS1 SBHN. PS1 52.530 SIGC.PS1 1.177 SIBH. PS1 72.197 TRAT. PS1 ~OF. PS1 1.095 SDSI.PS1 0.471 BACK. PSi 334.542 FBAC. PS1 TCAN. PS1 30873.305 TCAF. PS1 17431.180 TCND.PS1 24625.367 TCFD. PS1 TSCN. PS1 6152.861 TSCF. PS1 3473.928 INND.PS1 754.571 INFD.PS1 TENS.PSi -70.000 GR.PS1 12.172 CCL.PS1 0.021 DEPT. 10232.500 SIGM. PS1 24.415 TPHI.PS1 22.463 SBHF. PS1 SBHN. PS1 54.806 SIGC.PS1 1.049 SIBH. PS1 83.213 TRAT. PS1 ~4~OF. PS1 1.110 SDSI.PS1 0.562 BACK. PSI 315.248 FBAC. PS1 TCAN. PS1 35270.797 TCAF. PS1 16377.330 TCND.PS1 21377.016 TCFD.PS1 TSCN. PS1 3780.235 TSCF. PS1 1755.281 INND.PS1 837.141 INFD.PS1 TENS.PSi -70.000 GR.PS1 62.156 CCL.PS1 0.000 44.405 1.275 83.784 11041.830 661.729 50. 746 1.404 83. 372 7650. 887 468. 336 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 54 **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-IMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12183.5 10242.0 TDTP $ LOG HEADER DATA DATE LOGGED: 6- FEB- 97 SOFTWARE VERSION: CP 42.2 TIME LOGGER ON BOTTOM: 1412 5-FEB-97 TD DRILLER (FT) : 12180.0 TD LOGGER (FT) : 12182.0 TOP LOG INTERVAL (FT) : 10250.0 BOTTOM LOG INTERVAL (FT) : 12180.0 LOGGING SPEED (FPHR) : 900.0 · DEPTH CONTROL USED (YES/NO) NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : TOOL NUMBER TND 230 TNC 145 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 55 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) '. BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~IARKS'. CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469 '. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BASELINE PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 56 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI PS2 PU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNPS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PS2 505980 O0 000 O0 0 11 1 1 4 68 0000000000 ~4~OF PS2 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCAN PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCAFPS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCND PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 INND PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS2 LB 505980 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS2 GAPI 505980 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS2 V 505980 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 57 ** DATA ** DEPT. 12183.500 SIGM. PS2 SBFAV. PS2 54.806 SIGC. PS2 ~4MOF. PS2 1.110 SDSI.PS2 TCAN. PS2 35270.797 TCAF. PS2 TSCN. PS2 3780.235 TSCF. PS2 TENS.PS2 -70.000 GR.PS2 DEPT. 10242.500 SIGM. PS2 SBHN. PS2 53.217 SIGC.PS2 i~40F. PS2 0.946 SDSI.PS2 TCAN. PS2 28323.418 TCAF. PS2 TSCN. PS2 5854.966 TSCF. PS2 TENS.PS2 -75.000 GR.PS2 24 1 0 16377 1755 20 17. 1. O. 15047. 3110. 29. 415 TPHI.PS2 049 SIBH. PS2 562 BACK. PS2 330 TCND.PS2 281 INArD.PS2 703 CCL.PS2 22.463 SBHF. PS2 83.213 TROT. PS2 315.248 FBAC. PS2 21377.016 TCFD.PS2 837.141 INFD.PS2 0.013 50.746 1.404 83.372 7650.887 468.336 670 TPHI.PS2 15.986 SBHF. PS2 46.374 071 SIBH. PS2 75.213 TRAT. PS2 1.376 386 BACK. PS2 312.583 FBAC. PS2 72.443 357 TCND.PS2 23799.438 TCFD.PS2 9453.307 563 INND.PS2 795.800 INFD.PS2 456.472 172 CCL.PS2 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NLrM~ER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUI4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 12185.5 10242.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 58 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 6-FEB-97 CP 42.2 1412 5-FEB-97 12180.0 12182.0 10250.0 12180.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ TOOL NUMBER TND 230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NO~IZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 59 PUMPED 30 BBLS BORAX INTO FORMATION RANPASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RANFINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX1 PU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SBHI~BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX1 505980 O0 000 O0 0 12 1 1 4 68 0000000000 lv~fOFBX1 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 60 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) FBAC BX1 CPS 505980 O0 000 O0 0 12 1 1 4 TCANBX1 CPS 505980 O0 000 O0 0 12 1 1 4 TCAFBX1 CPS 505980 O0 000 O0 0 12 1 1 4 TCNDBX1 CPS 505980 O0 000 O0 0 12 1 1 4 TCFD BX1 CPS 505980 O0 000 O0 0 12 1 1 4 TSCN BX1 CPS 505980 O0 000 O0 0 12 1 1 4 TSCF BX1 CPS 505980 O0 000 O0 0 12 1 1 4 INArDBX1 CPS 505980 O0 000 O0 0 12 1 1 4 INFD BX1 CPS 505980 O0 000 O0 0 12 1 1 4 TENS BX1 LB 505980 O0 000 O0 0 12 1 1 4 GR BX1 GAPI 505980 O0 000 O0 0 12 1 1 4 CCL BX1 V 505980 O0 000 O0 0 12 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 12185.500 SIGM. BX1 35.973 TPHI.BX1 SBHN. BX1 177.209 SIGC.BX1 0.000 SIBH.BX1 ~OF.BX1 -0.045 SDSI.BX1 1.349 BACK.BX1 TCAN. BX1 0.000 TCAF.BX1 0.000 TCND.BX1 TSCN. BX1 0.000 TSCF.BX1 0.000 INND.BX1 TENS.BX1 -70.000 GR.BX1 9.813 CCL.BX1 0.000 SBHF. BX1 254.610 TRAT. BX1 24.732 FBAC. BX1 -309.226 TCFD.BX1 -0.841 INFD.BX1 -0.209 225.233 0.000 11.371 -134.931 -0.387 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE ~ 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 61 FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREFIENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH TDTP 12192.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10244.5 6-FEB-97 CP 42.2 1412 5-FEB-97 12180.0 12182.0 10250.0 12180.0 900.0 NO TOOL STRING (TOP TOBOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ TOOL NUMBER ........... TND 230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNTRATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 62 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BO~ INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 ** 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 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX2 PU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SBI4NBX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX2 505980 O0 000 O0 0 13 1 1 4 68 0000000000 l~40F BX2 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 BACK BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCNDBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 INFD BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX2 LB 505980 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX2 GAPI 505980 O0 000 O0 0 13 1 1 4 68 0000000000 CCL BX2 V 505980 O0 000 O0 0 13 1 1 4 68 0000000000 PAGE: 63 ** DATA ** DEPT. 12192.500 SIGM. BX2 51.393 TPHI.BX2 SBHN. BX2 78.039 SIGC.BX2 0.563 SIBH.BX2 I~IOF.BX2 0.979 SDSI.BX2 1.660 BACK.BX2 TCAN. BX2 12257.529 TCAF.BX2 3261.328 TCND.BX2 TSCN. BX2 460.319 TSCF.BX2 138.472 INND.BX2 TENS.BX2 -70.000 GR.BX2 17.047 CCL.BX2 DEPT. 10244.500 SIGM. BX2 18.425 TPHI.BX2 SBHN. BX2 81.712 SIGC. BX2 0.165 SIBH.BX2 Ivk4OF. BX2 0.954 SDSI.BX2 0.409 BACK.BX2 TCAN. BX2 22215.523 TCAF. BX2 11416.275 TCND.BX2 TSCN. BX2 4822.124 TSCF. BX2 2478.028 INND.BX2 TENS.BX2 -70.000 GR.BX2 29.297 CCL.BX2 47 217 170 987 187 182 10057 684 932 207 0 008 20.350 152.533 236.914 17180.941 852.476 0.000 SBHF. BX2 TRAT. BX2 FBAC.BX2 TCFD.BX2 INFD.BX2 SBHF.BX2 TRAT. BX2 FBAC. BX2 TCFD.BX2 INFD.BX2 71.603 1.338 40.534 2411.472 323.396 65. 190 1. 475 50. 584 6618. 371 368. 481 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 64 **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION · O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .014 SERVICE · FLIC VERSION · O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 14 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SU~VARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12190.0 10251.0 TDTP $ LOG HEADER DATA DATE LOGGED: 6-FEB- 97 SOFTWARE VERSION: CP 42.2 TIME LOGGER ON BOTTOM: 1412 5-FEB-97 TD DRILLER (FT) : 12180.0 TD LOGGER (FT) : 12182.0 TOP LOG INTERVAL (FT) : 10250.0 BOTTOM LOG INTERVAL (FT) : 12180.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER TND 230 TNC 145 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 66 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 66 1 66 0.5 FT 11 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SIGM BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TPHI BX3 PU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SBHF BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SBHNBX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SIGC BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SIBH BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TRAT BX3 505980 O0 000 O0 0 14 1 1 4 68 0000000000 I~OF BX3 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SDSI BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 BACK BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 FBAC BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCANBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCAFBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCNDBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCFDBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TSCN BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TSCF BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 INNDBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 INFD BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TENS BX3 LB 505980 O0 000 O0 0 14 1 1 4 68 0000000000 GR BX3 GAPI 505980 O0 000 O0 0 14 1 1 4 68 0000000000 CCL BX3 V 505980 O0 000 O0 0 14 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ** DEPT. SBHN. BX3 ~OF.BX3 TCAN. BX3 TSCN. BX3 TENS.BX3 12190 000 81 712 0 954 22215 523 4822 124 -70 000 SIGM. BX3 SIGC.BX3 SDSI.BX3 TCAF.BX3 TSCF. BX3 GR.BX3 DEPT. 10251.000 SBHIV. BX3 79.364 ~OF.BX3 1.036 TCAN. BX3 18925.363 TSCN. BX3 4280.315 TENS.BX3 -65.000 SIGM. SIGC. SDSI. TCAF. TSCF. GR. BX3 BX3 BX3 BX3 BX3 BX3 14-APR-1997 13:35 18.425 TPHI.BX3 0.165 SIBH.BX3 O. 409 BACK. BX3 11416. 275 TCND. BX3 2478. 028 INND. BX3 16.047 CCL.BX3 19 551 0 444 0 486 9851 674 2228 135 35 031 TPHI.BX3 SIBH.BX3 BACK. BX3 TCND.BX3 INND.BX3 CCL.BX3 20.350 SBHF. BX3 152.533 TRAT. BX3 236.914 FBAC. BX3 17180.941 TCFD.BX3 852.476 INFD.BX3 0.017 19.947 SBHF. BX3 141.406 TRAT. BX3 259.207 FBAC.BX3 16402.746 TCFD.BX3 877.466 INFD.BX3 0.000 PAGE: 65.190 1.475 50.584 6618.371 368. 481 61.930 1.422 50.153 6263.650 378.911 67 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION · O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .015 SERVICE ' FLIC VERSION · O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NLrM~ER 15 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 12185.5 10247.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PAGE: 68 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 6-FEB-97 CP 42.2 1412 5-FEB-97 12180.0 12182.0 10250.0 12180.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ TOOL NUMBER TND 230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #4. $ LIS FORMAT DATA PAGE: 69 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 66 1 66 0.5 FT 11 0 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 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SIGM BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TPHI BX4 PU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SBHF BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SBHNBX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SIGC BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SIBH BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TRAT BX4 505980 O0 000 O0 0 15 1 1 4 68 0000000000 ~OF BX4 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SDSI BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 BACK BX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) O0 O0 O0 O0 O0 FBAC BX4 CPS 505980 TCANBX4 CPS 505980 TCAFBX4 CPS 505980 TCNDBX4 CPS 505980 TCFD BX4 CPS 505980 TSCN BX4 CPS 505980 O0 TSCF BX4 CPS 505980 O0 INNDBX4 CPS 505980 O0 INFD BX4 CPS 505980 O0 TENS BX4 LB 505980 O0 GR BX4 GAPI 505980 O0 CCL BX4 V 505980 O0 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 000 O0 0 15 1 1 4 68 0000000000 PAGE: 7O ** DATA ** DEPT. 12185.500 SIGM. BX4 SBHN. BX4 64.073 SIGC.BX4 N~4OF.BX4 0.963 SDSI.BX4 TCAN. BX4 14110.764 TCAF.BX4 TSCN. BX4 806.544 TSCF. BX4 TENS.BX4 -70.000 GR.BX4 DEPT. 10247.500 SIGM. BX4 SBHN. BX4 53.666 SIGC.BX4 lffMOF.BX4 1.015 SDSI.BX4 TCAN. BX4 27236.176 TCAF.BX4 TSCN. BX4 5662.334 TSCF. BX4 TENS.BX4 -70.000 GR.BX4 48 877 0 000 1 435 3101 002 196 638 21 875 TPHI.BX4 75.844 SBHF. BX4 64.389 SIBH.BX4 125.387 TRAT. BX4 1.784 BACK.BX4 253.172 FBAC.BX4 50.802 TCND.BX4 12619.365 TCFD.BX4 2667.728 INND.BX4 921.777 INFD.BX4 265.682 CCL.BX4 0.008 17.673 TPHI.BX4 19.789 SBHF. BX4 48.159 0.999 SIBH.BX4 79.448 TRAT. BX4 1.521 0.377 BACK. BX4 267.057 FBAC. BX4 52.862 13024.238 TCND.BX4 23274.793 TCFD.BX4 8195.402 2707.707 INND.BX4 876.034 INFD.BX4 379.799 33.969 CCL.BX4 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NA~E : EDIT . O16 SERVICE : FLIC VERSION · O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 14-APR-1997 13: 35 PAGE: 71 FILE HEADER FILE NIIMBER 16 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 7 DEPTH INCREMENT: O. 5000 FILE SU~ffrzARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12184.5 10241.5 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 6-FEB-97 CP 42.2 1412 5-FEB-97 12180.0 12182.0 10250.0 12180.0 900.0 NO TOOL NUMBER TND 230 TNC 145 12283.0 BO~ & KCL 8.60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN) .. REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR THE FLUSHED PASS. $ LIS FORMAT DATA PAGE: 72 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APRil997 13:35 TYPE REPR CODE VALUE 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 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SIGM FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TPHI FLU PU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SBHF FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SBHNFLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SIGC FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SIBH FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TRAT FLU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 ~OF FLU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SDSI FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 BACK FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 FBAC FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCANFLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCAF FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCND FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCFD FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TSCN FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TSCF FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 INNDFLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 INFD FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TENS FLU LB 505980 O0 000 O0 0 16 1 1 4 68 0000000000 GR FLU GAPI 505980 O0 000 O0 0 16 1 1 4 68 0000000000 CCL FLU V 505980 O0 000 O0 0 16 1 1 4 68 0000000000 PAGE: 73 ** DATA ** DEPT. 12184 SBHN. FLU 53 ~k4OF. FLU 1 TCAN. FLU 2723 6 TSCN. FLU 5662 TENS. FLU - 70 500 SIGM. FLU 666 SIGC.FLU 015 SDSI.FLU 176 TCAF. FLU 334 TSCF. FLU 000 GR.FLU DEPT. 10241. 500 SBHN. FLU 53.110 ~40F. FLU O. 920 TCAN. FLU 26607. 375 TSCN. FLU 5559. 941 SIGM. FLU SIGC. FLU SDSI.FLU TCAF. FLU TSCF. FLU 17 673 0 999 0 377 13024 238 2707 707 27 313 TPHI.FLU 19.789 SBHF. FLU 48.159 SIBH.FLU 79.448 TRAT. FLU 1.521 BACK.FLU 267.057 FBAC. FLU 52.862 TCND.FLU 23274.793 TCFD.FLU 8195.402 INND.FLU 876.034 INFD.FLU 379.799 CCL.FLU 0.013 16.993 TPHI.FLU 17.820 SBHF. FLU 45.373 1 . 121 SIBH. FLU 76. 081 TRAT. FLU 1 . 470 O. 385 BACK. FLU 284. 604 FBAC. FLU 53. 260 13391. 020 TCND. FLU 23075. 781 TCFD. FLU 8283. 574 2798. 220 INND. FLU 830. 800 INFD. FLU 386. 572 LIS Tape Verification Listing Schlumberger Alaska Computing Center TENS. FLU - 70. 000 GR. FLU 14-APR-1997 13:35 35.438 CCL.FLU 0.000 PAGE 74 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .017 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE ArUI~BER 17 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 8 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12186.5 10240.5 TDTP $ LOG HEADER DATA DATE LOGGED: 6-FEB- 97 SOFTWARE VERSION: CP 42.2 TI~IE LOGGER ON BOTTOM: 1412 5-FEB-97 TD DRILLER (FT) : 12180.0 TD LOGGER (FT) : 12182.0 TOP LOG INTERVAL (FT) : 10250.0 BOTTOM LOG INTERVAL (FT) : 12180.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1997 13:35 TDTP THERMAL DECAY TDTP THERMAL DECAY $ TND 230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX & KCL 8.6O NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) '. BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHA1VNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR THE FLOWING PASS. LIS FOR24AT DATA PAGE: 75 ~ifi~ LIS Tape Verification Listing Schlumberger Alaska Computing Center ~5 14-APR-1997 13:35 PAGE: 76 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAIVE SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SIGM FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TPHI FLO PU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SBHF FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SBHNFLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SIGC FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SIBH FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TRAT FLO 505980 O0 000 O0 0 17 1 1 4 68 0000000000 ~4MOF FLO 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SDSI FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 BACK FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 FBAC FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCANFLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCAF FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCNDFLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCFD FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TSCN FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TSCF FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 INND FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 INFD FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TENS FLO LB 505980 O0 000 O0 0 17 1 1 4 68 0000000000 GR FLO GAPI 505980 O0 000 O0 0 17 1 1 4 68 0000000000 CCL FLO V 505980 O0 000 O0 0 17 1 1 4 68 0000000000 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER RECEIVED APR 0 4 1997 COMPANY NAME : BP EXPLORAION WELL NAME : B- 2A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292006601 REFERENCE NO : 97076 LIS Tape Verlrication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/03/31 ORIGIN : FLIC REEL NAME : 97076 CONTINUATION # : PREVIOUS REEL : COR~4~VT : BP EXPLORATION, B-2A, PRUDHOE BAY, API #50-029-20066-01 **** TAPE HEADER **** SERVICE NAlViE : EDIT DATE : 97/03/31 ORIGIN : FLIC TAPE NAME : 97076 CONTINUATION # : 1 PREVIOUS TAPE : COF~4~2~f : BP EXPLORATION, B-2A, PRUDHOE BAY, API #50-029-20066-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: B- 2A API NU~ER: 500292006601 OPERATOR: BP EXPLORAION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 31-MAR-97 JOB NU~IBER: 97076 LOGGING ENGINEER: J. PAWLUK OPERATOR WITNESS: S. WHIPP SURFACE LOCATION SECTION: 31 TOWNSHIP: 1 iN RANGE: 14E FNL : 961 FSL: FEL: 1598 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 59.70 DERRICK FLOOR: GROUND LEVEL: 40.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 5663.0 2ND STRING 7. 000 10385.0 3RD STRING 4. 500 1 O171.0 12.60 PRODUCTION STRING 4 . 500 12283 . 0 12. 60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 29-JULY-9 LOGGING COMPANY: ATLAS BASELINE DEPTH .............. 88888.0 12095.5 12090.0 12071.5 12053.5 12041.5 12025.5 12015.5 12008.0 12001.0 12000.5 11995.5 11984.5 11958.5 11958.0 11938.0 11936.0 11927.0 11914.0 11911.5 11885.0 11880.5 11865.0 11856.0 11854.5 11847.5 11823.5 11811.0 11751.0 11711.5 11695.0 11683.5 11679.0 11677.5 11660.5 11629.0 11617.0 11612.0 11595.5 11595.0 11593.5 11585.0 11568.0 11565.0 11557.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88886.5 88887.0 12094.0 12088.0 12071.0 12039.5 12024.5 12015.0 12007.0 12000.5 11994.0 11985.5 11959.0 11934.5 11912.5 11879.0 11864.5 11855.0 11847.5 11823 5 11812 0 11749 5 11711 5 11695 5 11683 5 11678.0 11659.0 11629.0 11612.0 11595.0 11592.0 11583.0 11567.0 12052.5 12000.0 11959.0 11941.0 11928.5 11910.5 11884.5 11854.5 11678.0 11616.5 11595.0 11567.0 11559.0 PAGE: LIS Tape Verl£ication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 11546.5 11545.5 11507.5 11493.0 11442.0 11435.5 11428.5 11425.5 11409.0 11400.0 11373.5 11371.0 11360.0 11359.0 11348.0 11331.0 11329.5 11307.5 11301.5 11295.0 11279.5 11253.5 11219.0 11216.5 11195.0 11173.5 11157.5 11138.0 11104.0 11096.5 11096.0 11062.5 11043.5 11027.5 11011.5 10995.5 10964 0 10910 5 10888 0 10883 0 10875 5 10842 5 10827.0 10819.5 10808.5 10807.0 10777.0 10775.5 10760.5 10744.0 10743.5 10739.5 10738.5 10735.0 10734.5 10731.0 11545.5 11506.5 11492.0 11441.0 11426.5 11425.0 11408.0 11400.0 11373.0 11359.0 11346.5 11329.5 11305.5 11294.0 11279.5 11252.5 11217.5 11215.0 11171.0 11136.0 11103.0 11095.5 11043.5 11011.5 10963. 0 10909.0 10886.5 10881.5 10873.0 10842.0 10826.5 10819.0 10807.5 10776.0 10743.0 10738. 0 10734.0 10730.5 11545.5 11434.5 11373.0 11357.5 11329.0 11301.0 11194.0 11156.5 11095.5 11062.5 11028.0 10996.0 10841.5 10807.5 10776.5 10759.5 10742.5 10738.5 10735.0 LIS Tape Verzrication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 10730.5 10710.5 10709.5 10697.5 10696.0 10692.0 10691.0 10680.5 10674.5 10660.5 10660.0 10647.5 10644.5 10638.5 10631.5 10630.5 10601.5 10594.0 10593.5 10582.5 10581 0 10568 5 10567 5 10560 0 10549 5 10545 0 10544 5 10543 5 10539 0 10524 0 10523 5 10514 5 10496 0 10495 0 10490 5 10486 5 10486.0 10463.0 10453.5 10453.0 10448.5 10448.0 10436.5 10432 5 10425 0 10424 5 10411 0 10402 0 100 0 $ 10709.5 10696.0 10690.5 10679.0 10672.5 10659.5 10645.0 10638.0 10629.5 10600.5 10592.5 10581.0 10566.0 10558.0 10548.0 10542.5 10539.0 10534.5 10521.5 10513.5 10494.0 10488.5 10484.5 10461.0 10451.5 10446.5 10434.5 10423.5 10409.0 10400.5 98.5 10729.5 10709.0 10695.5 10690.5 10659.5 10645.0 10629.5 10592.5 10581.0 10566.0 10542.0 10521.5 10493.5 10484.5 10460.5 10451.5 10446.5 10432.5 10423.5 99.0 CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON BP EXPLORATION'S B-2A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN BASELINE PASS #1 GRCHAND GR.BCS; AND BASELINE PASS #1 SIGMAND GR.BCS. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. PAGE: LIS Tape Ve~==ication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: **** FILE HEADER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-UMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREFiF2~f: O. 5000 FILE SUF~Vi~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12153.0 10236.0 TDTP 12182.0 1023 6.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUFi~ER : BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP REFiLl<S: THIS FILE CONTAINS TDTP BASELINE PASS #1. THERE WERE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: TYPE REPR CODE VALUE 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 1 i 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TSCFTDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12181.000 SIGM. TDTP 12.921 TPHI.TDTP 25.030 SBHF. TDTP 49.441 SBHN. TDTP 52.347 SIGC. TDTP 0.422 SIBH. TDTP 79.646 TRAT. TDTP 1.907 SDSI.TDTP 0.196 BACK. TDTP 83.983 FBAC. TDTP 26.418 TCAN. TDTP 77948.125 TCAF. TDTP 32521.676 TCND.TDTP 31701.223 TCFD. TDTP 10949.695 TSCN. TDTP 12634.797 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: TSCF. TDTP 5271 . 516 INND. TDTP 839. 859 TENS. TDTP -70. 000 CCL. TDTP O. 000 INFD. TDTP 376. 876 GRCH. TDTP -999.250 DEPT. 10234.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBItN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC.TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 57.844 TENS. TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~ff~%RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12146.0 10246.0 TDTP 12175.0 10246.0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUA~BER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: BASELINE DEPTH 88888.0 12166.5 12162.5 12158.5 12154.5 12150.5 12146.5 12138.5 12130.5 12126.5 12122.5 12110.5 12106.5 12104.5 12102.5 12100.5 12098.5 12092.5 12088.5 12084.5 12078.5 12074.5 12070.5 12060.5 12056.5 12052.5 12038.5 12034.5 12030.5 12026.5 12022.5 12018.5 12014.5 12010.5 12008.5 12006.5 12004.5 12002.5 12000.5 11998.5 11994.5 11990.5 11986.5 11982.5 11978 5 11974 5 11972 5 11970 5 11968 5 11966 5 11962 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.0 88887.5 12103.5 12100.0 12092.0 12087.5 12084.0 12060.0 12055.5 12051.0 12007.0 12003.5 12000.5 11972.5 11968.0 12166.0 12161.5 12156.0 12152.0 12149.0 12145.0 12138.0 12130.0 12126.5 12122.0 12110.0 12106.5 12102.0 12097.5 12077.5 12073.0 12069.5 12037.5 12034.0 12029.0 12025.5 12021.5 12018.0 12014.0 12010.5 12005.5 12001.5 11997.0 11993.5 11991.0 11986.5 11982.5 11979.0 11975.5 11971.0 11966.5 11964.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 11960.5 11958.5 11956.5 11954.5 11950.5 11946.5 11938 5 11934 5 11930 5 11926 5 11922 5 11918 5 11914.5 11910.5 11908.5 11904.5 11900.5 11896.5 11892.5 11890.5 11888.5 11886.5 11884.5 11880.5 11878.5 11876.5 11874.5 11870.5 11866.5 11864.5 11862.5 11860.5 11858.5 11854.5 11850.5 11846.5 11842.5 11838.5 11834.5 11818.5 11816.5 11814.5 11810.5 11806.5 11802.5 11794.5 11790.5 11786.5 11782.5 11778.5 11774.5 11770.5 11766.5 11758.5 11754.5 11958.5 11953.5 11907.5 11903.5 11900.0 11895.5 11892.0 11887.5 11884.0 11879.5 11876.0 11864.0 11860.5 11816.5 11959.5 11956.5 11952.5 11949.0 11941.0 11936.5 11931 5 11927 5 11923 0 11918 5 11914 0 11909 5 11889.5 11886.0 11878.0 11873.0 11870.0 11866.0 11861.5 11858.0 11854.5 11850.0 11846.5 11841.5 11838.0 11834.5 11818.5 11814.0 11810.0 11806.5 11802.0 11794.0 11789.5 11786.0 11780.5 11777.5 11774.5 11769.5 11766.0 11758.0 11752.5 LIS Tape Verzrication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 10 11750.5 11742.5 11738.5 11734.5 11730.5 11726.5 11722.5 11718.5 11716.5 11714.5 11710.5 11708.5 11706.5 11704.5 11702.5 11700.5 11696.5 11692.5 11690.5 11688.5 11686.5 11682.5 11678.5 11676.5 11674.5 11672.5 11670.5 11668.5 11666.5 11664.5 11662 5 11660 5 11658 5 11656 5 11654 5 11650 5 11646 5 11642.5 11638.5 11634.5 11630.5 11626.5 11622.5 11620.5 11618.5 11614.5 11610.5 11586.5 11584.5 11582.5 11578.5 11570.5 11566.5 11562.5 11554.5 11718.0 11710.0 11705.5 11702.0 11698.0 11693.5 11689.0 11677.0 11672.5 11669.0 11665.0 11660.5 11657.0 11621.0 11584.0 11750.0 11742.0 11737.5 11734.5 11729.0 11724.5 11720.0 11717.0 11712.5 11708.5 11705.0 11700.5 11688.5 11684.0 11680.5 11677.0 11672.5 11668.5 11665.5 11661.0 11656.5 11653.5 11649.0 11646.5 11641.0 11637.0 11632.0 11628.5 11626.0 11622.0 11617.5 11613.5 11610.0 11586.0 11583.5 11579.0 11571.0 11566.5 11563.0 11555.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 11 11550 5 11542 5 11538 5 11532 5 11528 5 11526 5 11524 5 11522.5 11518.5 11516.5 11514.5 11512.5 11510.5 11508.5 11506.5 11504.5 11502.5 11498.5 11494.5 11490.5 11486.5 11482.5 11470.5 11466.5 11462.5 11460.5 11458.5 11438.5 11434.5 11430.5 11426.5 11422.5 11420.5 11418.5 11414.5 11410.5 11402.5 11398.5 11392.5 11374.5 11370.5 11366.5 11362.5 11358.5 11354.5 11352.5 11350.5 11346.5 11342.5 11340.5 11338.5 11336.5 11332.5 11318.5 11314.5 11532.0 11527.5 11524.0 11516.0 11511.5 11508.0 11504.0 11458.5 11420.0 11392.0 11351.0 11339.0 11334.5 11331.0 11550.5 11542.5 11538.0 11526.0 11522.5 11518.0 11514.0 11509.0 11504.5 11499.5 11497.0 11493.0 11489.5 11485.0 11480.5 11468.5 11465.0 11460.5 11457.0 11437.0 11432.5 11428.0 11425.5 11422.5 11418.0 11414.5 11410.0 11402.0 11397.5 11373.5 11370.0 11364.5 11360.0 11356.0 11352.5 11349.0 11345.5 11343.0 11337.5 11317.5 11312.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 12 11306.5 11302.5 11300.5 11298.5 11294.5 11290.5 11286.5 11274.5 11270.5 11266.5 11262.5 11246.5 11242.5 11238.5 11230.5 11226.5 11222.5 11214.5 11210.5 11206.5 11202.5 11198.5 11194.5 11190.5 11186.5 11182.5 11178.5 11174.5 11170.5 11150.5 11146.5 11142.5 11138.5 11134.5 11126.5 11122.5 11118.5 11110.5 11106.5 11102.5 11094.5 11090.5 11086.5 11082.5 11078.5 11074.5 11070.5 11054.5 11050.5 11046.5 11042.5 11018.5 11014.5 11010.5 11002.5 11299.0 11306.0 11301.5 11297.5 11294.0 11290.0 11285.5 11273.5 11269.0 11266.5 11261.5 11245.5 11241.0 11237 5 11229 5 11224 5 11221 0 11213 0 11210 5 11205 0 11200 5 11196.5 11193.5 11189.5 11185.0 11181.0 11177.5 11173.5 11169.0 11149.0 11146.0 11142.0 11137.5 11133.0 11126.5 11122.0 11117.5 11109.5 11105.0 11101.5 11093.5 11090.0 11084.0 11081 0 11077 5 11073 5 11070 0 11054 0 11049 5 11046 0 11042.5 11018.5 11014.0 11009.5 11002.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 13 10998.5 10999.0 10994.5 10995.0 10990.5 10990.5 10982.5 10982.5 10978.5 10978.0 10974.5 10975.0 10970.5 10970.0 10966.5 10966.0 10962.5 10962.5 10958.5 10958.5 10954.5 10953.5 10946.5 10945.5 10944.5 10942.5 10942.5 10941.0 10940.5 10938.5 10938.5 10937.0 10934.5 10934.5 10930.5 10930.5 10926.5 10926.0 10922.5 10921.0 10920.5 10918.0 10914.5 10913.0 10910.5 10909.5 10906.5 10905.5 10902.5 10903.0 10898.5 10899.0 10894.5 10894.0 10892.5 10890.0 10890.5 10889.0 10888.5 10885.5 10886.5 10885.0 10884.5 10882.0 10882.5 10881.5 10878.5 10877.5 10874.5 10873.0 10870.5 10869.0 10866.5 10863.0 10864.5 10862.0 10862.5 10858.0 10860.5 10858.5 10848.5 10846.5 10844.5 10843.5 10842.5 10840.5 10840.5 10840.0 10838.5 10836.5 10836.5 10834.5 10834.5 10833.5 10832.5 10832.0 10828.5 10827.0 10826.5 10825.5 10824.5 10824.0 10822.5 10822.0 10820.5 10819.5 10818.5 10818.0 10814.5 10815.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 14 10810.5 10804.5 10800.5 10798.5 10796.5 10794.5 10792.5 10790 5 10788 5 10786 5 10784 5 10782 5 10780 5 10778 5 10774 5 10772.5 10770.5 10768.5 10766.5 10762.5 10760.5 10756.5 10746.5 10742.5 10738.5 10734.5 10730.5 10726.5 10724.5 10722.5 10720.5 10718.5 10716.5 10712.5 10710.5 10706.5 10704.5 10702.5 10700.5 10690.5 10686.5 10682.5 10678.5 10674.5 10670.5 10666.5 10660.5 10658.5 10656.5 10654.5 10650.5 10646.5 10803.5 10799.0 10795.0 10790.5 10786.0 10782.5 10779.0 10771.0 10767.5 10759.5 10755.0 10723.0 10719.5 10715.5 10711.0 10703.0 10698.5 10658.5 10654.0 10810.5 10798.5 10794.0 10790.0 10786.5 10783.0 10779.5 10774.5 10769.0 10764.0 10761.0 10745.0 10741.5 10738.0 10734.0 10729.5 10725.0 10722.0 10717.5 10709.5 10706.5 10701.5 10689.5 10685.0 10681.0 10677.5 10674.0 10670.0 10665.5 10657.5 10654.0 10650.5 10646.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SBI{NTDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 16 ** DATA ** DEPT. 12174.500 SIGM. TDTP SBHN. TDTP 43.895 SIGC. TDTP SDSI. TDTP 0.141 BACK. TDTP TCAF. TDTP 48280.266 TCND. TDTP TSCF. TDTP 5394.808 INND. TDTP TENS.TDTP -70.000 CCL.TDTP DEPT. 10244.000 SIGM. TDTP SBHN. TDTP 51.856 SIGC. TDTP SDSI.TDTP 0.426 BACK. TDTP TCAF. TDTP 14537.646 TCND. TDTP TSCF. TDTP 3007.061 INND. TDTP TENS. TDTP -70.000 CCL. TDTP 11. 418 TPHI. TDTP 21.231 SBHF. TDTP O. 928 SIBH. TDTP 54 . 918 TRAT. TDTP 214. 831 FBAC. TDTP 50. 376 TCAN. TDTP 31552. 031 TCFD. TDTP 11093. 031 TSCN. TDTP 860. 162 INFD. TDTP 350.174 GRCH. TDTP 0.000 18 527 1 068 314 535 23543 746 791 775 0 000 TPHI. TDTP SIBH. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 16. 782 SBHF. TDTP 72. 250 TRAT. TDTP 73. 859 TCAN. TDTP 9277. 473 TSCN. TDTP 483. 888 GRCH. TDTP 31.311 1.833 111546.984 12464.191 -999.250 42.196 1.392 28022.535 5796.362 26.734 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE · 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH GRCH 12147.0 TDTP 12176.0 STOP DEPTH 10246.0 10246.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 17 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12155.0 12149.0 12126.0 12096.0 12087.5 12071 0 12065 5 12058 5 12057 0 12050 5 12049 5 12044 5 12040 0 12030.0 12001.0 11986.0 11976.5 11966.5 11960.5 11951.5 11938.5 11926.0 11917.0 11913.0 11911.5 11907.5 11898.0 11885.0 11865.5 11861.5 11860.5 11855.5 11853.0 11848.5 11832.0 11824.0 11797.5 11792.0 11776.5 11700.5 11691.0 11675.0 11631.0 11606.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH ....... 88888.0 12087.5 12071.0 12055.5 12048.5 12039.5 12028.5 12000.5 11976.5 11961.0 11912.5 11865.0 11859.5 11855.0 11848.0 11823.5 11791.0 11690.0 11631.0 11605.5 TDTP 88887.0 12154.0 12147.5 12125.5 12095.5 12065.0 12058.0 12048.5 12043.5 12000.5 11985.5 11978.5 11966.5 11952.5 11941.5 11928.5 11916.5 11910.0 11906.5 11897.5 11884.0 11861.0 11853.0 11832.0 11797.0 11775.5 11700.0 11674.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 18 11595.5 11577 0 11566 0 11557 0 11552 5 11545 0 11524 5 11503 0 11482 5 11461 5 11450 5 11427 5 11417 0 11408, 0 11404 0 11394.0 11374.5 11373.5 11359.0 11358.5 11334.5 11333.5 11330.0 11292.5 11281.0 11249.0 11243.0 11237.0 11195.0 11157.5 11096.5 11096.0 11044.5 11025.0 11009.5 10996.5 10986.5 10977.5 10966.0 10934.5 10905.0 10888.5 10864.0 10835.0 10819.0 10808.0 10806.5 10796.5 10777 0 10775 5 10762 5 10760 5 10744 5 10743 5 10739.0 11576.5 11551.5 11524.5 11502.5 11461.0 11416.0 11403.0 11372.5 11357.5 11331.5 11291.0 11240.0 11155.0 11095.5 11043.5 11009.5 10985.5 10965.5 10933.0 10902.5 10886.5 10863.5 10819.0 10807.5 10794.5 10776.0 10759.5 10743.0 10738.5 11595.0 11567.0 11559.0 11545.0 11481.5 11449.5 11426.0 11406.5 11393.0 11373.5 11356.5 11333.5 11329.0 11280.5 11248.0 11236.5 11194.0 11095.5 11026.0 10996.5 10978.0 10834.0 10807.0 10776.0 10759.5 10742.5 LIS Tape Ver=£ication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 19 10738.5 10733.0 10731.5 10719.5 10716.5 10710.0 10699.5 10697.5 10692.0 10691.5 10660.5 10660.0 10644.5 10631.5 10631.0 10616.5 10602.0 10594.0 10593.5 10587.5 10582.0 10581.0 10568.5 10567.5 10559.0 10545.0 10531.5 10523.5 10498.5 10490.5 10486.5 10485.5 10478.0 10463.0 10453.5 10448.5 10448.0 10425 0 10424 0 10400 0 10393 0 10385 5 10384 0 10381 0 10378 5 10375 5 10372 5 10371 0 10367 5 10362 5 10352 5 10346 0 10339 5 10337.5 10336.5 10730.5 10709.5 10695.5 10690.5 10659.5 10629.5 10600.5 10592.5 10586.5 10581.0 10566.0 10521.5 10488.5 10484.5 10451.5 10446.5 10423.5 10392.0 10384.0 10379.5 10374.0 10369.5 10361.0 10344.5 10337.5 10335.0 10738.5 10732.5 10719.0 10715.5 10698.5 10690.5 10659.5 10645.0 10629.5 10616.5 10601.5 10592.5 10581.0 10566.0 10556.0 10541.5 10529.0 10496.5 10484.0 10476.0 10461.0 10451.5 10446.5 10423.5 10399.0 10383.0 10378.0 10371.5 10367.0 10351.5 10337.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 2O 10332.5 10331 . 0 10331.5 10331.0 10329.5 10328.0 10329.0 10328.5 10327.5 10326.0 10321 . 5 10320.0 10318.5 10317.0 10312.5 10311.0 10311.5 10310.5 10304.0 10302.5 10303 . 5 10302.5 10294.0 10293.0 10289.0 10287.5 10276.0 10275.0 10272.5 10271.0 10271.5 10270.5 10257.0 10256.5 100.0 98.5 99.5 $ REMARKS: THIS FILE CONTAINS THE TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #1 GRCH TO BASELINE PASS #1 GRCH, AND BORAX PASS #1 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT i1 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 21 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~I CODE (HEX) DEPT FT 505980 SIGM TDTP CU 505980 TPHI TDTP PU-S 505980 SBHF TDTP CU 505980 SBHNTDTP CU 505980 SIGC TDTP CU 505980 SIBH TDTP CU 505980 TRAT TDTP 505980 SDSI TDTP CU 505980 BACK TDTP CPS 505980 FBAC TDTP CPS 505980 TCAN TDTP CPS 505980 TCAF TDTP CPS 505980 TCND TDTP CPS 505980 TCFD TDTP CPS 505980 TSCN TDTP CPS 505980 TSCF TDTP CPS 505980 INND TDTP CPS 505980 INFD TDTP CPS 505980 GRCH TDTP GAPI 505980 TENS TDTP LB 505980 CCL TDTP V 505980 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 .3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12175.000 SIGM. TDTP 13 SBH~.TDTP 62.457 SIGC. TDTP 0 SDSI.TDTP 0.164 BACK. TDTP 25 TCAF. TDTP 23490.492 TCND.TDTP 27894 TSCF. TDTP 4636.660 INND.TDTP 843 TENS.TDTP -70.000 CCL.TDTP 0 DEPT. 10244.500 SIGM. TDTP -999 SBBiN. TDTP -999.250 SIGC. TDTP -999 SDSI.TDTP -999.250 BACK. TDTP -999 TCAF. TDTP -999.250 TCND. TDTP -999 TSCF. TDTP -999.250 INND. TDTP -999 TENS.TDTP -999.250 CCL.TDTP -999 170 TPHI.TDTP 27.246 SBHF. TDTP 40.109 306 SIBH. TDTP 110. 437 TRAT. TDTP 1. 957 049 FBAC. TDTP 11 . 877 TCAN. TDTP 57479. 633 379 TCFD. TDTP 9644 . 225 TSCN. TDTP 11345. 592 811 INFD. TDTP 378. 082 GRCH. TDTP -999. 250 000 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 250 FBAC. TDTP -999. 250 TCAN. TDTP -999. 250 250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 250 INFD. TDTP -999. 250 GRCH. TDTP 25. 188 250 ** END OF DATA ** LIS Tape Ver~£ication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 22 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO ~T FILE : FILE HEADER FILE NUM~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREmENT: 0.5000 FILE SU~k~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12154.0 10248.0 TDTP 12183.0 10248.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88887.0 12103.0 12102.5 12090.5 12088.0 12082.5 12081.5 12071.0 12071.0 12066.0 12065.0 12060.5 12058.0 12050.5 12048.5 12047.5 12045.0 12040.5 12039.5 12015.0 12014.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 23 12001.0 11988.0 11958.0 11944.5 11938.0 11923.0 11908.0 11898.0 11866.0 11863.0 11861.0 11859.5 11853.5 11846.5 11832.0 11822.0 11815.5 11797.5 11790.5 11776.5 11755.0 11742 5 11722 5 11694 0 11692 0 11677 5 11640 5 11617 5 11608 0 11591 5 11580.5 11572.0 11557.5 11545.5 11538.5 11526.0 11519.0 11497.5 11483.5 11450.5 11426.0 11394.0 11374.0 11373.5 11358.5 11334.5 11330.0 11324.0 11302.0 11283.0 11282.5 11249.0 11238.0 11216.5 11177.5 12000.5 11988.0 11922.0 11864.5 11862.0 11859.5 11847.0 11815.5 11791.0 11743.5 11724.5 11694.5 11678.0 11607.5 11524.5 11426.5 11373.0 11329.0 11281.0 11958.5 11946.0 11941.0 11906.5 11897.5 11857.5 11853.0 11832.0 11821.5 11797.0 11775.5 11754.0 11690.5 11639.0 11617.0 11590.5 11580.5 11573.0 11559.0 11545.5 11537.5 11520.0 11496.5 11482.0 11449.5 11393.0 11373.0 11356.5 11333.5 11329.0 11323.5 11301.5 11283.0 11247.5 11237.5 11215.5 11176.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 24 11170.5 11161.5 11127.5 11096 5 11080 5 11067 0 11025 0 11012 5 10995 5 10978 0 10967 0 10941 5 10925 0 10889 0 10835 5 10832.0 10819.5 10815.0 10807.5 10807.0 10797.0 10785.0 10777.5 10775.0 10761.0 10760.5 10744.5 10743.5 10739.5 10738.5 10735.0 10733.0 10732.0 10720.5 10710.5 10709.5 10699.0 10697.5 10692.0 10691.5 10661.0 10660.0 10648.0 10646.5 10644.5 10640.0 10631.5 10630.5 10602.5 10594.0 10593.5 10588.0 10580.5 10578.5 10568.5 11169.5 11095.5 11065.5 11011.5 10965.5 10923.0 10886.5 10831.5 10819.0 10814.0 10807.5 10783.5 10776.0 10760.0 10743.0 10738.0 10734.0 10730.5 10709.5 10696.0 10690.5 10659.5 10645.0 10629.5 10600.5 10592.5 10586.5 10577.0 10566.0 11159.5 11127.0 11095.5 11079.5 11026.0 10996.0 10977.5 10940.5 10834.0 10807.5 10797.0 10776.5 10759.5 10743.0 10738.5 10732.5 10720.5 10708.5 10698.5 10690.5 10659.5 10648.0 10644.5 10640.0 10629.5 10601.5 10592.5 10580.5 10566.0 LIS Tape Ver~£ication Listing Schlumberger,Alaska Computing Center 31-MAR-1997 14:18 PAGE: 25 10560.0 10558.0 10559.0 10556.0 10544.5 10542.0 10536.0 10534.0 10524.5 10522.0 10523.5 10521.5 10510.5 10508.5 10500.5 10499.0 10493.0 10491.0 10486.5 10484.5 10485.5 10484.0 10478.0 10476.5 10465.0 10463.5 10463.0 10460.5 10454.0 10452.0 10453.0 10451.5 10451.5 10448.5 10448.5 10446.5 10448.0 10446.5 10441.0 10440.0 10433.0 10432.0 10428.0 10427.0 10425.5 10423.5 10424.5 10423.5 10420.0 10420.0 10407.0 10406.0 10403.0 10400.5 10391.0 10390.0 10386.0 10384.0 10384.0 10382.0 10383.0 10381.0 10379.5 10379.0 10378.0 10375.5 10373.5 10374.5 10373 . 0 10371 . 5 10368.5 10366.5 10359.5 10357.5 10356.5 10355.0 10352.0 10351.5 10347.5 10346.5 10343.0 10342.0 10339.5 10337.5 10336.5 10335.0 10332.5 10331.0 10332.0 10331.0 10330.0 10328.0 10321.5 10320.0 10319.0 10317.5 10316.5 10315.0 10313.0 10311.5 10312.0 10311.0 10304.5 10302.5 10303.5 10302.5 10294.5 10293.0 10288.5 10287.5 10287.0 10286.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 26 10276.5 10275.5 10274.0 10272.5 10270.5 10271.5 10264.5 10263.5 100.0 99.0 $ 10275.0 10270.5 99.0 REMARKS: THIS FILE CONTAINS TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT BORAX PASS #2 GRCH TO BASELINE PASS #1 GRCH, AND BORAX PASS #2 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE N~4B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SIBH TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TSCNTDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 4 1 1 4 68 0000000000 GRCHTDTP GAPI 505980 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12182. 000 SIGM. TDTP 13. 379 TPHI. TDTP 26. 475 SBHF. TDTP SBPiN. TDTP 65.538 SIGC. TDTP O. 136 SIBH. TDTP 117.910 TRAT. TDTP SDSI. TDTP O. 211 BACK. TDTP 144. 215 FBAC. TDTP 47. 059 TCAN. TDTP TCAF. TDTP 18704. 289 TCND. TDTP 27764. 574 TCFD. TDTP 9841 . 211 TSCN. TDTP TSCF. TDTP 4730. 706 INND. TDTP 938. 294 INFD. TDTP 350. 287 GRCH. TDTP TENS. TDTP -70. 000 CCL. TDTP O. 000 DEPT. 10247. 000 SIGM. TDTP 18. 430 TPHI. TDTP 20. 600 SBHF. TDTP SBPiN. TDTP 77. 485 SIGC. TDTP O. 298 SIBH. TDTP 140. 905 TRAT. TDTP SDSI. TDTP O. 367 BACK. TDTP 233. 906 FBAC. TDTP 48.1 79 TCAN. TDTP TCAF. TDTP 10937. 943 TCND. TDTP 17217. 699 TCFD. TDTP 6674 . 519 TSCN. TDTP TSCF. TDTP 2433. 679 INND. TDTP 858. 304 INFD. TDTP 375. 694 GRCH. TDTP TENS. TDTP - 70. 000 CCL. TDTP O. 000 43. 175 1. 914 44919. 844 11361. 170 -999. 250 63. 853 1. 484 21617. 625 4809. 896 25. 828 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Ver~£ication Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 28 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFiBER: 6 DEPTH INCRENF2q~: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12153.0 10254.0 TDTP 12182.0 10254.0 $ CURVE SHIFT DATA - PASS TO PASS (~4~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER: 1 BASELINE DEPTH 88888.0 12109.0 12108.0 12097.0 12081.0 12071.5 12067.0 12057.0 12054.5 12044.5 12040.5 12024.5 12015.5 11994.5 11969.5 11959.5 11945.0 11933.5 11924.0 11912.0 11908.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88886.5 12107.5 12071.0 12056.0 12039.5 12024.0 12014.5 11994.0 11969.5 88887.5 12107.5 12095.0 12079.5 12065.0 12052.5 12043.5 11959.0 11947.0 11935.5 11925.5 11910.0 11906.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 29 11904 0 11902 5 11898 5 11864 5 11859 0 11858 0 11856 0 11848 0 11822 0 11805.0 11798.5 11776.5 11683.5 11678.5 11677.0 11628.5 11625.5 11617.0 11599.5 11592.5 11580.0 11578.5 11570.0 11557.5 11546.5 11525.0 11498.5 11495.0 11451.0 11435.5 11423.5 11416.5 11408.5 11395.0 11375.5 11359.5 11337 5 11334 5 11331 0 11330 5 11325 0 11300 0 11275.0 11251.0 11249.0 11238.5 11224.0 11215.5 11196.5 11195.5 11179.0 11119.0 11097.0 11091.0 11044.0 11903.0 11864.5 11859.0 11855.0 11847.0 11683.5 11678.5 11629.0 11579.0 11524.5 11498.0 11424.5 11336.0 11329.5 11275.0 11250.5 11196.5 11090.5 11043.0 11902.5 11898.0 11857.0 11821.0 11805.0 11797.5 11776.0 11675.0 11624.5 11615.5 11598.0 11590.5 11580.5 11570.5 11559.0 11545.5 11493.5 11449.5 11434.0 11415.5 11407.0 11393.0 11373.0 11357.0 11333.5 11329.0 11323.5 11299.0 11247.5 11237.0 11222.5 11215.0 11194.0 11176.5 11117.0 11095.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 3O 11026.0 10996 5 10988 5 10985 0 10984 5 10978 5 10967 0 10959.5 10931.5 10917.5 10888.5 10882.5 10843.0 10836.0 10832.5 10820.0 10816.0 10809.5 10807.5 10789.0 10783.0 10778.5 10776.0 10760.5 10760.0 10745.5 10745.0 10740.5 10740.0 10735.0 10734.0 10732.5 10720.5 10712.0 10710.0 10700.0 10692.5 10692.0 10683.5 10661.0 10656.0 10652.5 10647.5 10641.0 10636.0 10632.5 10631.5 10603.0 10594.5 10583.5 10582.0 10569.5 10568.5 10559.0 10556.0 10984.0 10965.5 10931.5 10886.5 10841.5 10831.5 10819.0 10814.0 10809.0 10786.5 10776.0 10759.5 10742.5 10738.0 10733. S 10730.5 10709.5 10690.5 10645.0 10629.5 10600.5 10592.5 10581.0 10566.0 11026.0 10996.5 10988.0 10984.0 10978.0 10958.0 10914.5 10880.5 10834.5 10807.5 10783.5 10776.0 10759.0 10743.0 10738.5 10732.5 10719.5 10708.5 10698.5 10690.5 10681.5 10660.0 10654.5 10652.0 10640.0 10634.5 10629.5 10601.5 10592.5 10581.0 10566.0 10556.0 10552.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 31 10544.5 10531.5 10524.5 10487.5 10486.5 10468.5 10466.0 10463.5 10454.5 10454.0 10449.5 10449.0 10441.0 10433.5 10425.5 10425.0 10392.0 10386.5 10384.5 10382.0 10379.5 10378.0 10376.0 10374.0 10371.5 10362.5 10352.5 10346.0 10340.0 10338.0 10336.5 10333 0 10332 5 10330 5 10328 5 10322 5 10319 5 10315 5 10313 0 10312 0 10302.0 10297.0 10294.5 10289.5 10280.0 10276.5 10273.0 10272.0 10264.0 100.0 $ 10522.0 10484.5 10463.5 10451.5 10446.5 10423.5 10384.5 10382.0 10379.5 10375.5 10373.5 10369.5 10360.5 10344.0 10337.5 10334.5 10331.0 10328.5 10326.5 10320.0 10317.5 10311.0 10300.0 10295.5 10287.5 10277.5 10271.0 10263.5 99.5 10541.5 10528.5 10521.5 10484.5 10465.5 10460.5 10451.5 10446.5 10440.0 10432.5 10423.5 10390.0 10383.0 10378.0 10371.5 10351.5 10336.5 10331.0 10315.0 10310.5 10293.0 10274.5 10270.5 98.5 THIS FILE CONTAINS TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #3 GRCH TO BASELINE PASS #1 GRCH, AND BORAX PASS #3 SIGM TO BASELINE PASS #1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 32 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 L~S Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 33 NANiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INND TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12181. 500 SIGM. TDTP 13. 490 TPHI. TDTP SBPiN. TDTP 63. 995 SIGC. TDTP O. 110 SIBH. TDTP SDSI. TDTP O. 224 BACK. TDTP 207. 392 FBAC. TDTP TCAF. TDTP 33472.250 TCND. TDTP 26767.930 TCFD.TDTP TSCF. TDTP 5003.479 INND. TDTP 798.887 INFD. TDTP TENS. TDTP -70.000 CCL.TDTP 0.000 DEPT. 10252. 500 SIGM. TDTP 19. 988 TPHI. TDTP SBHN. TDTP 79.546 SIGC. TDTP O. 242 SIBH. TDTP SDSI. TDTP O. 480 BACK. TDTP 265. 442 FBAC. TDTP TCAF. TDTP 9284. 008 TCND. TDTP 16266. 111 TCFD. TDTP TSCF. TDTP 2103. 868 INND. TDTP 895. 453 INFD. TDTP TENS. TDTP -70. 000 CCL. TDTP O. 000 23. 907 SBHF. TDTP 110. 474 TRAT. TDTP 47. 389 TCAN. TDTP 10213 . 988 TSCN. TDTP 285. 027 GRCH. TDTP 19. 257 SBHF. TDTP 144. 059 TRAT. TDTP 55. 421 TCAN. TDTP 6320. 362 TSCN. TDTP 376. 318 GRCH. TDTP 50.846 1.808 74765.969 11176.125 -999.250 66.071 1.382 17718.559 4015.238 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE · 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 34 FILE HEADER FILE ~ER .. 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUN~ER : 7 DEPTH INCREMENT: O. 5000 FILE SU~E4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12148.0 10250.0 TDTP 12177.0 10250.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 BASELINE DEPTH 88888.0 12130.0 12122.5 12107.5 12104 0 12098 0 12093 0 12090 5 12081 0 12072 0 120670 12051.0 12041.5 12027.0 12009.0 11996.5 11989.0 11972.0 11968.0 11958.0 11952.5 11938.0 11934.0 11917.5 11908.5 11900.0 11899.5 11866.5 11861.0 11853.5 11849.5 11834.5 11822.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP .............. 88886.0 88888.0 12128.0 12121.0 12102.5 12092.0 12088.0 12071.0 12048.5 12039.0 12025.5 12007.0 11994.0 11988.0 11972.0 11898.5 11864.5 11859.5 11848.0 11835.0 12107.5 12095.0 12080.0 12065.0 11967.0 11958.0 11953.0 11941.0 11935.5 11916.5 11906.5 11898.0 11853.0 11821.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 35 11812.5 11812.0 11798.5 11792.0 11776.5 11773.5 11772.5 11766.5 11759.5 11758.0 11737.0 11736.5 11701.0 11685.0 11683.5 11679.5 11678.5 11676.0 11672.5 11629.5 11617.5 11608.0 11599.5 11596.0 11593.0 11581.0 11571.0 11559.0 11546.0 11524.0 11523.5 11524.5 11463.0 11465.0 11451.5 11427.0 11421.0 11425.0 11409.0 11394.5 11359.0 11338.5 11337.5 11340.0 11330.0 11324.5 11302.5 11296.0 11282.0 11279.0 11281.0 11272.0 11249.5 11239.5 11240.5 11239.0 11224.0 11210.0 11208.0 11196.0 11178.5 11175.0 11174.0 11161.5 11135.5 11097.0 11095.0 11026.0 10996.5 10978.0 11797.5 11791.0 11775.5 11766.0 11700.0 11674.5 11670.5 11627.5 11616.5 11607.5 11597.5 11594.5 11590 5 11580 5 11570 5 11559 5 11545 5 11522 5 11449.5 11426.5 11407.0 11393.0 11357.0 11337.0 11329.0 11323.5 11301.5 11295.5 11280.5 11270.5 11247.5 11237.0 11222.5 11194.0 11177.0 11159.5 11134.0 11095.5 11026.0 10996.5 10977.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 36 10958.5 10958.0 10888.5 10886.5 10884.0 10882.0 10882.0 10880.5 10865.0 10863 . 5 10843 . 0 10841 . 5 10836.0 10834 . 5 10833 . 0 10834 . 0 10820.0 10819.5 10815.5 10814.0 10808.0 10808.0 10807.0 10807.0 10788.5 10786.5 10777.0 10776.5 10776.0 10774.0 10761 . 0 10759.5 10744.5 10742.5 10743.0 10739.5 10738.0 10739.0 10734.5 10733.5 10733.5 10732.5 10732.0 10730.5 10715.5 10715.0 10711.0 10709.5 10705.5 10704.5 10698.0 10696.0 10696.5 10695.5 10692.0 10690.5 10690.5 10661 . 0 10659.0 10660.0 10659.5 10648.5 10648.0 10645.0 10645.0 10634.0 10632.5 10632.0 10629.5 10594.5 10592.5 10594.0 10592.5 10583.0 10581.0 10582.0 10581.0 10569.5 10566.0 10568.0 10566.0 10559.0 10556.0 10544.5 10541 . 0 10528.5 10525.5 10524.5 10521.5 10524.0 10521.5 10511.5 10508.5 10498.5 10496.5 10491 . 0 10488.5 10487.0 10484.5 10486.5 10484.5 10468.5 10465.5 10463 . 5 10460.5 10454.0 10452.0 10453.5 10451 . 5 10452.0 10449.0 10449.0 10446.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 37 10441.0 10435 0 10433 5 10427 5 10425 5 10424 5 10391 0 10386 0 10384.5 10381.5 10379.0 10376.0 10373.0 10369.5 10364.0 10360.0 10353.0 10346.0 10340.0 10338.5 10337.0 10333.0 10332.5 10330.0 10325.5 10319.5 10313.0 10312.0 10310.0 10307.0 10304.5 10304.0 10296.5 10294.5 10291.0 10277.5 10276.5 10273.0 10272.0 100.0 $ 10433.0 10423.5 10384.0 10379.5 10374.0 10363.0 10358.0 10344.0 10337.5 10335.0 10331.0 10328.0 10323.5 10317.5 10311.5 10308.0 10306.5 10302.5 10296.0 10289.0 10276.0 10271.0 98.0 10440.0 10432.5 10426.5 10423.0 10390.0 10383.5 10378.0 10374.5 10372.0 10368.5 10352.0 10337.0 10331.0 10310.5 10302.5 10293.0 10274.5 10270.5 98.5 REMARKS: THIS FILE CONTAINS BORAX PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #4 GRCH TO BASELINE PASS #1 GRCH, AND BORAX PASS #4 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 38 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~iE 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 505980 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN TDTP CU 505980 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI'TDTP CU 505980 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 39 ** DATA ** DEPT. 12177.000 SIGM. TDTP 12.277 TPHI.TDTP SBHN. TDTP 60.926 SIGC. TDTP 0.527 SIBH. TDTP SDSI.TDTP 0.176 BACK. TDTP 149.001 FBAC. TDTP TCAF. TDTP 18502.293 TCND. TDTP 26140.836 TCFD. TDTP TSCF. TDTP 4666.404 INND. TDTP 805.053 INFD. TDTP TENS. TDTP -70.000 CCL.TDTP 0.000 22,947 101,113 29,393 9390.807 338,144 SBHF. TDTP TRAT. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP 46.508 1.823 41981.625 10588.051 -999.250 DEPT. 10248.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999,250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999,250 TCAN. TDTP -999.250 TCAF. TDTP -999,250 TCND. TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999,250 INND. TDTP -999.250 INFD. TDTP -999,250 GRCH. TDTP 28.563 TENS. TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUAiBER: 8 DEPTH INCREMENT: 0.5000 FILE SU~9~%RY LDWG TOOL CODE START DEPTH ......................... GRCH 12147.0 TDTP 12167.0 STOP DEPTH 10245.0 10245.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 40 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 12151 0 12130 5 12127 5 12109 0 12096 0 12095 0 12084.0 12080.0 12071.0 12066.5 12049.5 12045.5 12040.5 12022.5 12018.0 12014.0 12004.5 12002.0 11978.5 11969.0 11957.5 11938.0 11916.5 11911.5 11907.5 11898.5 11878.0 11864.5 11855.5 11854.0 11831.5 11824.5 11797.5 11775.0 11759.5 11752.0 11684.5 11680.0 11678.5 11650.5 11617.5 11605.5 11598.0 11594.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88885.0 88887.5 12127.5 12107.0 12094.0 12081.5 12071.0 12048.5 12039.5 12024.0 12014.5 12000.5 11970.0 11879.5 11864.5 11855.0 11823.5 11758.5 11683.5 11678.0 11605.5 12150.5 12125.5 12095.5 12079.5 12065.0 12045.0 12018.0 12004.5 11978.5 11958.5 11941.0 11916.5 11910.0 11906.5 11897.5 11854.0 11831.5 11797.0 11775.0 11754.0 11678.0 11649.0 11617.0 11597.5 11594.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 41 11592 0 11580 0 11566 0 11558 0 11555 5 11546 5 11523 5 11509 5 11482 5 11464 0 11450.5 11439.5 11434.5 11394.5 11378.0 11333.0 11331.0 11329.5 11328.0 11325.0 11296.0 11248.5 11237.5 11216.5 11195.0 11159.0 11097.0 11096.0 11045.5 11028.0 10996.0 10888.0 10874.0 10842.5 10835.0 10819.0 10818.5 10808.0 10806.0 10781.5 10777 0 10772 5 10759 5 10743 5 10739 0 10738 0 10734.0 10733.0 10732.5 10711.0 10709.5 10697.5 10696.0 10692.0 10691.5 11555.0 11509.5 11465.5 11441.0 11331.0 11330.0 11326.0 11294.0 11095.5 11043.5 10886.0 10873.0 10842.0 10819.0 10807.5 10775.5 10743.0 10738.5 10733.5 10730.5 10709.5 10696.0 10690.5 11590.5 11580.5 11567.5 11559.0 11545.5 11523.0 11481.0 11449.5 11434.0 11393.0 11377.5 11329.0 11323.5 11247.5 11237.0 11215.5 11194.0 11156.5 11095.5 11028.0 10996.5 10834.5 10818.5 10807.0 10782.5 10772.5 10758.5 10742.5 10738.5 10732.5 10709.0 10695.5 10691.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 42 10660.5 10660.0 10651.5 10646.0 10644.0 10640.0 10631.5 10630.0 10602.5 10594.0 10593.5 10589.5 10581.5 10581.0 10568.5 10567.5 10563.0 10559.0 10544.0 10531.0 10524.5 10523.5 10510.5 10500.5 10490.5 10486.5 10485 5 10468 0 10463 0 10453 5 10453 0 10448 5 10425 0 10424 0 10390 5 10385 5 10384 0 10381 0 10378 5 10375 5 10372 5 10370 5 10367.5 10362.0 10352.5 10346.5 10338.0 10336.0 10332.5 10332.0 10318.5 10312.5 10312.0 10304.0 10294.0 10659.5 10644.5 10629.5 10592.5 10588.0 10581.0 10566.0 10521.5 10488.5 10484.5 10451.5 10446.5 10423.5 10384.0 10379.5 10373.5 10361.0 10345.5 10334.5 10331.0 10317.0 10311.0 10302.5 10659.5 10651.5 10644.5 10640.0 10629.5 10601.5 10592.5 10581.0 10566.5 10559.5 10556.0 10541.5 10528.5 10522.0 10508.5 10499.0 10484.0 10465.5 10460.5 10451.5 10423.5 10390.0 10383.0 10378.0 10371.5 10370.0 10367.0 10351.5 10337.0 10331.0 10311.0 10303.0 10293.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 43 10288.5 10287.5 10275.5 10275.0 10272.5 10271.0 10271.5 10270.5 10260.0 10259.0 100.0 98.5 99.0 $ REMARKS: THIS FILE CONTAINS THE TDTP FLUSHED PASS. THE DEPTH SHIFTS SHOWN ABOVEREFLECT FLUSHED PASS GRCH TO BASE- LINE PASS #1 GRCH, AND FLUSHED PASS SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~iE 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 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SBPZN TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 44 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) SIBH TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 7 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 7 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12166.500 SIGM. TDTP 16.205 TPHI.TDTP 28.821 SBHF. TDTP 42.275 SBHN. TDTP 43.550 SIGC. TDTP 0.000 SIBH. TDTP 56.388 TRAT. TDTP 1.950 SDSI.TDTP 0.348 BACK. TDTP 198.216 FBAC. TDTP 38.938 TCAN. TDTP 46129.500 TCAF. TDTP 18344.855 TCND. TDTP 26306.551 TCFD.TDTP 8576.979 TSCN. TDTP 9510.936 TSCF. TDTP 3782.324 INND. TDTP 842.993 INFD. TDTP 298.530 GRCH. TDTP -999.250 TENS. TDTP -70.000 CCL. TDTP 0.000 DEPT. 10243.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBtiN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD.TDTP -999.250 GRCH. TDTP 36.719 TENS. TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 45 **** FILE HEADER **** FILE NA~E : EDIT .008 SERVICE · FLIC VERSION : O01CO1 DATE ' 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N73MBER: 8 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER .. 1 DEPTH INCREMENT: O. 5000 FILE SUPff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12148.0 10244.0 TDTP 12177.0 10244.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFfl3ER : 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88889.0 88887.5 12174.0 12173.5 12152.5 12152.0 12141.5 12142.5 12133.0 12133.0 12117.0 12118.5 12104.0 12105.5 12100.0 12100.0 12098.5 12097.5 12096.0 12095.0 12080.5 12080.0 12071.0 12071.0 12066.0 12065.0 12052.5 12052.0 12049.5 12048.5 12045.0 12044.0 12040.5 12039.5 12021.0 12020.5 12008.5 12007.0 12000.5 12000.0 11995.0 11994.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 46 11987.5 11979.0 11969.5 11966.0 11958.0 11956.5 11951.0 11937.5 11926.5 11916.5 11911.5 11911.0 11898.0 11882.5 11864.0 11862.0 11860.0 11855.5 11853.0 11838.0 11824.0 11821.0 11815.5 11811.5 11797.5 11790.5 11786.5 11775.0 11770.0 11754 5 11691 0 11684 5 11679 0 11675 5 11667 0 11649 0 11626.0 11599.5 11595.0 11594.5 11579.5 11560.5 11558.5 11545.5 11537.5 11497.5 11495.5 11482.0 11450.5 11440.5 11426.5 11407.0 11402.0 11394.0 11374.0 11988.0 11971.0 11959.0 11950.0 11912.5 11865.0 11862.0 11855.0 11823.5 11812.0 11683.5 11678.0 11595.0 11557.5 11534.5 11493.5 11441.0 11403.0 11979.0 11965.5 11959.0 11951.5 11941.0 11928.0 11916.0 11910.0 11897.5 11882.0 11860.0 11853.0 11838.0 11821.0 11815.5 11811.5 11797.5 11791.0 11784.5 11776.0 11768.5 11754.0 11690.5 11674.0 11666.5 11648.5 11624.5 11598.5 11595.0 11580.5 11559.0 11545.0 11497.0 11481.5 11449.5 11425.5 11406.5 11393.0 11372.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 47 11330 0 11329 5 11323 5 11299 5 11291 0 11280 5 11248 5 11238 5 11224 5 11208 5 11206.5 11196.0 11161.0 11128.0 11120.0 11096.5 11066.5 11047.5 10996.0 10988.0 10964.5 10935.0 10903.5 10888.0 10882.5 10881.0 10869.0 10854.0 10849.5 10841.5 10836.0 10835.5 10827.5 10815.5 10808.0 10807.5 10782.0 10777.5 10761.0 10744.5 10744.0 10740.0 10739.5 10734.0 10733.0 10731.5 10720.5 10711 0 10709 5 10699 5 10697 5 10692 0 10661 0 10660 5 10652 5 11329.5 11291.0 11208.0 11120.0 11095.5 11065.5 10985.5 10963.0 10933.0 10886.0 10881.5 10867.5 10854.0 10841.5 10834.5 10826.5 10814.0 10807.5 10776.0 10742.5 10738.5 10733.0 10730.5 10709.0 10696.0 10690.5 10659.5 11329.5 11323.5 11299.0 11280.0 11247.5 11237.0 11222.5 11206.0 11194.5 11159.0 11127.0 11096.0 11047.0 10996.5 10905.5 10880.5 10847.5 10834.5 10807.5 10783.0 10759.5 10742.5 10738.5 10732.0 10719.5 10708.5 10698.5 10691.0 10659. S 10652.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 48 10645.0 10645.0 10640.5 10640.0 10636.0 10635.0 10631.5 10629.5 10631.0 10630.0 10618.0 10616.0 10602.5 10601.5 10594.5 10592.5 10594.0 10592.5 10583.0 10581.0 10581.5 10581.0 10568.5 10566.0 10568.0 10566.0 10559.0 10556.0 10545.0 10541.5 10537.5 10534.0 10528.5 10525.5 10524.0 10521.5 10516.0 10513.5 10511.0 10508.0 10491.0 10488.5 10487.0 10484.5 10486.5 10484.5 10467.5 10465.5 10463.5 10460.5 10459.0 10457.0 10453.5 10451.5 10451.5 10449.0 10446.5 10448.0 10446.5 10441.0 10439.5 10433.5 10432.5 10428.0 10427.0 10425.0 10423.5 10424.5 10423.5 10402.5 10400.5 10391.5 10390.0 10386.5 10384.0 10384.5 10383.0 10381.0 10379.5 10379.0 10378.0 10375.5 10373.5 10374.5 10373.0 10371.5 10367.5 10367.0 10362.5 10361.0 10352.5 10351.5 10346.0 10344.0 10338.0 10336.5 10336.5 10334.5 10332.5 10331.0 10332.0 10330.5 10330.0 10328.0 10322.0 10320.5 10319.0 10317.0 10313.0 10311.0 10312.0 10310.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 49 10304.0 10302.5 10303.0 10294.5 10293.5 10290.5 10289.0 10276.5 10275.0 10272.5 10270.5 10272.0 10270.5 10258.0 10256.5 100.0 98.0 98.5 $ REMARKS: THIS FILE CONTAINS THE TDTP FLOWING PASS. THE DEPTH SHIFTS SHOWN ABOVEREFLECT FLOWING PASS GRCH TO BASE- LINE PASS #1 GRCH, AND FLOWING PASS SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E 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 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SIGMTDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI TDTP PU-S 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 5O 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) SBHNTDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT TDTP 505980 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI TDTP CU 505980 O0 000 O0 0 8 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCAN TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCND TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TSCNTDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 INND TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 INFD TDTP CPS 505980 O0 000 O0 0 8 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 8 1 1 4 68 0000000000 TENS TDTP LB 505980 O0 000 O0 0 8 1 1 4 68 0000000000 CCL TDTP V 505980 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 12176.500 SIGM. TDTP 12.672 TPHI.TDTP 25.307 SBHF. TDTP SBHN. TDTP 52.157 SIGC. TDTP 0.418 SIBH. TDTP 79.260 TRAT. TDTP SDSI.TDTP 0.167 BACK. TDTP 38.276 FBAC. TDTP 12.900 TCAN. TDTP TCAF. TDTP 25782.965 TCND. TDTP 33214.406 TCFD. TDTP 11532.658 TSCN. TDTP TSCF. TDTP 5468.007 INND. TDTP 841.413 INFD. TDTP 412.356 GRCH. TDTP TENS.TDTP -70.000 CCL.TDTP 0.000 DEPT. 10242 . 000 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 37.457 1.930 62693.375 13295.902 -999.250 -999.250 -999.250 -999.250 -999.250 21.953 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 51 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE . FLIC VERSION · O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NTJRiBER: 9 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP THE ARITHMETIC AVERAGE OF THE BASELINE PASSES (l&2) WAS CALCULATED AFTER CLIPPING ANDDEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 52 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI~SS MOD NUMB S.~/JP ELETVl CODE (HEX) DEPT FT 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PNAV PU-S 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SBPiNPNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PNAV 505980 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PNAV CU 505980 O0 000 O0 0 9 1 1 4 68 0000000000 BACK TDTP CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC TDTP CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TCAFPNAV CPS 505980 O0 000 O0 0 9 1 1 4 68' 0000000000 TCND PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 INND PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PNAV CPS 505980 O0 000 O0 0 9 1 1 4 68 0000000000 GRCH TDTP GAPI 505980 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 12181.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV SDSI.PNAV -999.250 BACK. TDTP 83.983 FBAC. TDTP 26.418 TCAN. PNAV TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP DEPT. 10234.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 57.844 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3i-MAR-1997 14:18 PAGE: 53 **** FILE TRAILER **** FILE NA~E : F~DIT .009 SERVICE . FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE · FLIC VERSION : O01CO1 DATE · 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12190.0 10232.0 TDTP LOG HEADER DATA DATE LOGGED: 6-FEB-97 SOFTWARE VERSION: CP 42.2 TIME LOGGER ON BOTTOM: 1412 5-FEB-97 TD DRILLER (FT) : 12180.0 TD LOGGER (FT) : 12182.0 TOP LOG INTERVAL (FT) : 10250.0 BOTTOM LOG INTERVAL (FT) : 12180.0 LOGGING SPEED (FPHR): 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER TND 230 TNC 145 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 54 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEG?) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO .. CHOKE (DEG) : BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BASELINE PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 55 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS1 PU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SBt{NPS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PSi CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS1 505980 O0 000 O0 0 10 1 1 4 68 0000000000 I4MOF PS1 505980 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS1 CU 505980 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCAFPS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCNDPS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS1 CPS 505980 O0 000 O0 0 10, 1 1 4 68 0000000000 INND PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS1 CPS 505980 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS1 LB 505980 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS1 GAPI 505980 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS1 V 505980 O0 000 O0 0 10 1 1 4 68 0000000000 ~fica LIS Tape Verification Listing Schlumberger Alaska Computing Center 18 31-MAR-1997 14:18 PAGE: 56 ** DATA ** DEPT. 12190.000 SIGM. PSl SBHN. PSi 52.530 SIGC. PS1 ~OF. PS1 1.095 SDSI.PS1 TCAN. PS1 30873.305 TCAF. PS1 TSCN. PS1 6152.861 TSCF. PS1 TENS.PSi -70.000 GR.PS1 DEPT. 10232 SBHN. PS1 54 ~340F. PS1 1 TCAN. PS1 35270 TSCN. PS1 3780 TENS.PSi -70 500 SIGM. PS1 806 SIGC. PS1 110 SDSI.PS1 797 TCAF. PS1 235 TSCF. PS1 000 GR.PS1 19.154 TPHI.PS1 14.342 1.177 SIBH. PS1 72.197 0.471 BACK. PSI 334.542 17431.180 TCND.PS1 24625.367 3473.928 INND.PS1 754.571 12.172 CCL.PS1 0.021 24.415 TPHI.PS1 1.049 SIBH. PS1 0.562 BACK. PSI 16377.330 TCND.PS1 1755.281 IArND.PS1 62.156 CCL.PS1 22.463 83.213 315.248 21377.016 837.141 0.000 SBHF. PS1 TRAT. PS1 FBAC. PS1 TCFD. PS1 INFD.PS1 SBHF. PS1 TRAT. PS1 FBAC. PS1 TCFD.PS1 INFD.PS1 44.405 1.275 83.784 11041.830 661.729 50. 746 1 . 404 83.372 7650. 887 468. 336 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT . O10 SERVICE : FLIC VERSION · O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMmArY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 12183.5 10242.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 58 PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BASELINE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 66 1 66 0.5 FT 11 0 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 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI PS2 PU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNPS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PS2 505980 O0 000 O0 0 11 1 1 4 68 0000000000 ~4~OF PS2 505980 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS2 CU 505980 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 59 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FBAC PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCAN PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCND PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 INND PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS2 CPS 505980 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS2 LB 505980 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS2 GAPI 505980 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS2 V 505980 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 12183.500 SIGM. PS2 24.415 TPHI.PS2 22.463 SBHF. PS2 SBHN. PS2 54.806 SIGC. PS2 1.049 SIBH.PS2 83.213 TRAT. PS2 MMOF. PS2 1.110 SDSI.PS2 0.562 BACK. PS2 315.248 FBAC. PS2 TCAN. PS2 35270.797 TCAF. PS2 16377.330 TCND.PS2 21377.016 TCFD.PS2 TSCN. PS2 3780.235 TSCF. PS2 1755.281 INND.PS2 837.141 INFD.PS2 TENS.PS2 -70.000 GR.PS2 20.703 CCL.PS2 0.013 DEPT. 10242.500 SIGM. PS2 17.670 TPHI.PS2 15.986 SBHF. PS2 SBHN. PS2 53.217 SIGC. PS2 1.071 SIBH.PS2 75.213 TRAT. PS2 I~MOF. PS2 0.946 SDSI.PS2 0.386 BACK.PS2 312.583 FBAC. PS2 TCAN. PS2 28323.418 TCAF. PS2 15047.357 TCND.PS2 23799.438 TCFD.PS2 TSCN. PS2 5854.966 TSCF. PS2 3110.563 INND.PS2 795.800 INFD. PS2 TENS.PS2 -75.000 GR.PS2 29.172 CCL.PS2 0.000 50.746 1.404 83.372 7650.887 468.336 46.374 1.376 72.443 9453.307 456.472 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 60 **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREmENT: 0.5000 FILE SU~Jh~Y VE2V~OR TOOL CODE START DEPTH STOP DEPTH 12185.5 10242.5 TDTP LOG HEADER DATA DATE LOGGED: 6- FEB- 97 SOFTWARE VERSION.. CP 42.2 TI~E LOGGER ON BOTTOM: 1412 5-FEB-97 TD DRILLER (FT) : 12180.0 TD LOGGER (FT) : 12182.0 TOP LOG INTERVAL (FT) : 10250.0 BOTTOM LOG INTERVAL (FT) : 12180.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO) .. NO TOOL STRING (TOP TOBOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER ........... TND 230 TNC 145 12283.0 BORAX & KCL 8.60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 61 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARE1VT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970 ' ~11990 ' AND 12012 ' -12032 '. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 62 TYPE REPR CODE VALUE 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 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BXi CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX1 PU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SBP~NBX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX1 505980 O0 000 O0 0 12 1 1 4 68 0000000000 MMOF BX1 505980 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX1 CU 505980 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TCANBX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TCAF BX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDBX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TCFDBX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN BX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF BX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 INNDBX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 INFD BX1 CPS 505980 O0 000 O0 0 12 1 1 4 68 0000000000 TENS BX1 LB 505980 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX1 GAPI 505980 O0 000 O0 0 12 1 1 4 68 0000000000 CCL BX1 V 505980 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 12185.500 SIGM. BX1 SBHN. BX1 177.209 SIGC.BX1 I~IOF.BX1 -0.045 SDSI.BX1 TCAN. BX1 0.000 TCAF.BX1 TSCN. BX1 0.000 TSCF.BX1 TENS.BX1 -70.000 GR.BX1 35.973 TPHI.BX1 0.000 SBHF. BX1 225.233 0.000 SIBH.BX1 254.610 TRAT. BX1 0.000 1.349 BACK.BX1 24.732 FBAC.BX1 11.371 0.000 TCND.BX1 -309.226 TCFD. BX1 -134.931 0.000 INND.BX1 -0.841 INFD.BX1 -0.387 9.813 CCL.BX1 -0.209 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 63 **** FILE TRAILER **** FILE NA~4~ : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE · 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 5 DEPTH INCREMENT: 0.5000 FILE SUM~D%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 12192.5 10244.5 TDTP LOG HEADER DATA DATE LOGGED: 6-FEB-97 SOFTWARE VERSION: CP 42.2 TIM~ LOGGER ON BOTTOM: 1412 5-FEB-97 TD DRILLER (FT) : 12180.0 TD LOGGER (FT) : 12182.0 TOP LOG INTERVAL (FT) : 10250.0 BOTTOM LOG INTERVAL (FT) : 12180.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER TND 230 TNC 145 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 64 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE .. FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 12283.0 BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUN~ RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~IAPJ~S: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469 '. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970 ' -11990 ' AND 12012 ' -12032 '. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 65 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E 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 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX2 PU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SBHNBX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX2 505980 O0 000 O0 0 13 1 1 4 68 0000000000 f4~OF BX2 505980 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI BX2 CU 505980 O0 000 O0 0 13 1 1 4 68 0000000000 BACK BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCNDBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TCFDBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 INFD BX2 CPS 505980 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX2 LB 505980 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX2 GAPI 505980 O0 000 O0 0 13 1 1 4 68 0000000000 CCL BX2 V 505980 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 66 ** DATA ** DEPT. 12192.500 SIGM. BX2 SBHN. BX2 78.039 SIGC.BX2 ~4~OF. BX2 0.979 SDSI.BX2 TCAN. BX2 12257.529 TCAF.BX2 TSCN. BX2 460.319 TSCF. BX2 TENS.BX2 -70.000 GR.BX2 DEPT. 10244.500 SIGM. BX2 SBPiN. BX2 81.712 SIGC.BX2 ~OF.BX2 0.954 SDSI.BX2 TCAN. BX2 22215.523 TCAF. BX2 TSCN. BX2 4822.124 TSCF.BX2 TENS.BX2 -70.000 GR.BX2 51.393 TPHI.BX2 47.217 SBHF. BX2 0.563 SIBH.BX2 170.987 TRAT. BX2 1.660 BACK. BX2 187.182 FBAC.BX2 3261.328 TCND.BX2 10057.684 TCFD.BX2 138.472 INND.BX2 932.207 INFD.BX2 17.047 CCL.BX2 0.008 18.425 TPHI.BX2 0.165 SIBH.B~2 0.409 BACK.BX2 11416.275 TCND.BX2 2478.028 INND.BX2 29.297 CCL.BX2 20.350 SBHF. BX2 152.533 TRAT. BX2 236.914 FBAC.BX2 17180.941 TCFD.BX2 852.476 INFD.BX2 0.000 71.603 1.338 40.534 2411.472 323.396 65. 190 1. 475 50. 584 6618. 371 368. 481 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE · 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 14 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUM~iARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 12190.0 10251.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 67 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION.. TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ 6~FEB-97 CP 42.2 1412 12180.0 12182.0 10250.0 12180.0 900.0 NO 5-FEB-97 TOOL NUMBER ........... TND230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 68 PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469 '. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 66 1 66 0.5 FT 11 0 FT 68 1 1 ** SET TYPE - CHAN ** NAFiE 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 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SIGM BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TPHI BX3 PU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SBHF BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SBHNBX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SIGC BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SIBH BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TRAT BX3 505980 O0 000 O0 0 14 1 1 4 68 0000000000 t4MOF BX3 505980 O0 000 O0 0 14 1 1 4 68 0000000000 SDSI BX3 CU 505980 O0 000 O0 0 14 1 1 4 68 0000000000 BACK BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 69 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FBAC BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCANBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCAFBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCNDBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TCFDBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TSCN BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TSCF BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 INNDBX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 INFD BX3 CPS 505980 O0 000 O0 0 14 1 1 4 68 0000000000 TENS BX3 LB 505980 O0 000 O0 0 14 1 1 4 68 0000000000 GR BX3 GAPI 505980 O0 000 O0 0 14 1 1 4 68 0000000000 CCL BX3 V 505980 O0 000 O0 0 14 1 1 4 68 0000000000 ** DATA ** DEPT. 12190.000 SIGM. BX3 18.425 TPHI.BX3 SBHN. BX3 81.712 SIGC.BX3 0.165 SIBH. BX3 ~OF.BX3 0.954 SDSI.BX3 0.409 BACK.BX3 TCAN. BX3 22215.523 TCAF. BX3 11416.275 TCND.BX3 TSCN. BX3 4822.124 TSCF. BX3 2478.028 INND.BX3 TENS.BX3 -70.000 GR.BX3 16.047 CCL.BX3 DEPT. 10251.000 SIGM. BX3 19.551 TPHI.BX3 SBHN. BX3 79.364 SIGC.BX3 0.444 $IBH.BX3 ~OF.BX3 1.036 SDSI.BX3 0.486 BACK.BX3 TCAN. BX3 18925.363 TCAF.BX3 9851.674 TCND.BX3 TSCN. BX3 4280.315 TSCF.BX3 2228.135 INND.BX3 TENS.BX3 -65.000 GR.BX3 35.031 CCL.BX3 20 350 152 533 236 914 17180 941 852 476 0 017 19.947 141.406 259.207 16402.746 877.466 0.000 SBHF.BX3 TRAT. BX3 FBAC.BX3 TCFD.BX3 INFD.BX3 SBHF. BX3 TRAT. BX3 FBAC.BX3 TCFD.BX3 INFD.BX3 65.190 1. 475 50. 584 6618. 371 368. 481 61.930 1.422 50.153 6263.650 378.911 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 70 **** FILE HEADER **** FILE NAM~ : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIM~ER 15 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 7 DEPTH INCREk4ENT: 0.5000 FILE SUP~VIAi~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12185.5 10247.5 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIf4E LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 6-FEB-97 CP 42.2 1412 5-FEB-97 12180.0 12182.0 10250.0 12180.0 900.0 NO TOOL NUMBER TND230 TNC 145 12283.0 BORAX & KCL 8.60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 71 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RAN FINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 72 TYPE REPR CODE VALUE 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 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SIGM BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TPHI BX4 PU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SBHF BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SBPiNBX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SIGC BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SIBH BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TRAT BX4 505980 O0 000 O0 0 15 1 1 4 68 0000000000 ~4MOF BX4 505980 O0 000 O0 0 15 1 1 4 68 0000000000 SDSI BX4 CU 505980 O0 000 O0 0 15 1 1 4 68 0000000000 BACK BX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 FBAC BX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TCANBX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TCAFBX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TCNDBX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TCFDBX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TSCN BX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TSCF BX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 INNDBX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 INFD BX4 CPS 505980 O0 000 O0 0 15 1 1 4 68 0000000000 TENS BX4 LB 505980 O0 000 O0 0 15 1 1 4 68 0000000000 GR BX4 GAPI 505980 O0 000 O0 0 15 1 1 4 68 0000000000 CCL BX4 V 505980 O0 000 O0 0 15 1 1 4 68 0000000000 ** DATA ** DEPT. 12185.500 SIGM. BX4 48 877 TPHI.BX4 75.844 SBHF.BX4 64.389 SBPiN. BX4 64.073 SIGC. BX4 0 000 SIBH.BX4 125.387 TRAT. BX4 1.784 ~4MOF. BX4 0.963 SDSI.BX4 1 435 BACK.BX4 253.172 FBAC.BX4 50.802 TCAN. BX4 14110.764 TCAF.BX4 3101 002 TCND.BX4 12619.365 TCFD.BX4 2667.728 TSCN. BX4 806.544 TSCF.BX4 196 638 INND.BX4 921.777 INFD.BX4 265.682 TENS.BX4 -70.000 GR.BX4 21 875 CCL.BX4 0.008 DEPT. 10247.500 SIGM. BX4 17.673 TPHI.BX4 19.789 SBHF. BX4 48.159 SBHN. BX4 53.666 SIGC.BX4 0.999 SIBH.BX4 79.448 TRAT. BX4 1.521 I~MOF.BX4 1.015 SDSI.BX4 0.377 BACK.BX4 267.057 FBAC. BX4 52.862 TCAN. BX4 27236.176 TCAF. BX4 13024.238 TCND.BX4 23274.793 TCFD.BX4 8195.402 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 73 TSCN. BX4 5662.334 TSCF.BX4 2707.707 INND.BX4 TENS.BX4 -70.000 GR.BX4 33.969 CCL.BX4 876.034 INFD.BX4 0.000 379.799 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE~ER 16 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 8 DEPTH INCREMENT: 0.5000 FILE SO?4FL~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 12184.5 10241.5 TDTP LOG HEADER DATA DATE LOGGED: 6-FEB-97 SOFTWARE VERSION: CP 42.2 TIME LOGGER ON BOTTOM: 1412 5-FEB-97 TD DRILLER (FT) : 12180.0 TD LOGGER (FT) : 12182.0 TOP LOG INTERVAL (FT) : 10250.0 BOTTOM LOG INTERVAL (FT) : 12180.0 LOGGING SPEED (FPHR): 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 74 VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY $ TOOL NUMBER ........... TND230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEC): BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RAN PASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RAN PASS 3. PUMPED 145 BBLS OF WATER AND RANFINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR THE FLUSHED PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 75 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SIGM FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TPHI FLU PU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SBHF FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SBHNFLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SIGC FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SIBH FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TRAT FLU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 ~OF FLU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 SDSI FLU CU 505980 O0 000 O0 0 16 1 1 4 68 0000000000 BACK FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 FBAC FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCANFLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCAFFLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCNDFLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TCFDFLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TSCN FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TSCF FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 INNDFLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 INFD FLU CPS 505980 O0 000 O0 0 16 1 1 4 68 0000000000 TENS FLU LB 505980 O0 000 O0 0 16 1 1 4 68 0000000000 GR FLU GAPI 505980 O0 000 O0 0 16 1 1 4 68 0000000000 CCL FLU V 505980 O0 000 O0 0 16 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 76 ** DATA ** DEPT. SBHN. FLU M~OF.FLU TCAN. FLU TSCN. FLU TENS.FLU 12184 500 53 666 1 015 27236 176 5662 334 -70 000 DEPT. 10241.500 SBHN. FLU 53.110 ~OF. FLU 0.920 TCA1V. FLU 26607.375 TSCN. FLU 5559.941 TENS.FLU -70.000 SIGM. FLU 17.673 TPHI.FLU 19.789 SBHF. FLU SIGC.FLU 0.999 SIBH. FLU 79.448 TRAT. FLU SDSI.FLU 0.377 BACK. FLU 267.057 FBAC.FLU TCAF.FLU 13024.238 TCND.FLU 23274.793 TCFD.FLU TSCF. FLU 2707.707 INND.FLU 876.034 INFD.FLU GR.FLU 27.313 CCL.FLU 0.013 SIGM. FLU 16 SIGC. FLU 1 SDSI.FLU 0 TCAF. FLU 13391 TSCF. FLU 2798 GR.FLU 35 993 TPHI.FLU 17.820 SBHF. FLU 121 SIBH. FLU 76.081 TRAT. FLU 385 BACK.FLU 284.604 FBAC. FLU 020 TCND.FLU 23075.781 TCFD. FLU 220 INND.FLU 830.800 INFD.FLU 438 CCL.FLU 0.000 48.159 1.521 52.862 8195.402 379.799 45.373 1.470 53.260 8283.574 386.572 ** EArD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .017 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 17 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMPLARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 77 TDTP 12186.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP T~ERMAL DECAY $ 10240.5 6-FEB-97 CP 42.2 1412 5-FEB-97 12180.0 12182.0 10250.0 12180.0 900.0 NO TOOL NUMBER TND 230 TNC 145 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 12283.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX & KCL 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 78 REYzARKS: CORRELATED TO ATLAS ACOUSTILOG DATED 29-JUL-96, MAIN PASS. PUMPED 180 BBLS WATER RAN BASELINE. PUMPED 30 BBLS BORAX INTO FORMATION RANPASS 1. PUMPED 30 MORE BBLS BORAX INTO FORMATION RAN PASS 2. PUMPED 40 MORE BBLS BORAX INTO FORMATION RANPASS 3. PUMPED 145 BBLS OF WATER AND RANFINAL PASS. APPARENT GOC IS 11469'. THERE IS A CHANNEL BETWEEN THE PERFS AT 11970'-11990' AND 12012'-12032'. THIS FILE CONTAINS THE RAW TDTP DATA FOR THE FLOWING PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 92 1 0.5 FT 11 1 2 3 4 5 6 7 8 68 9 65 11 66 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 ELE~ CODE (HEX) DEPT FT 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SIGM FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TPHI FLO PU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SBHF FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SBHNFLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SIGC FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 SIBH FLO CU 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TRAT FLO 505980 O0 000 O0 0 17 1 1 4 68 0000000000 f4~OF FLO 505980 O0 000 O0 0 17 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 79 NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) O0 000 O0 0 17 1 1 4 68 0000000000 SDSI FLO CU 505980 BACK FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 FBAC FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCANFLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCAFFLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCND FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TCFD FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TSCN FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TSCF FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 IN-NDFLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 INFD FLO CPS 505980 O0 000 O0 0 17 1 1 4 68 0000000000 TENS FLO LB 505980 O0 000 O0 0 17 1 1 4 68 0000000000 GR FLO GAPI 505980 O0 000 O0 0 17 1 1 4 68 0000000000 CCL FLO V 505980 O0 000 O0 0 17 1 1 4 68 0000000000 ** DATA ** DEPT. 12186.500 SIGM. FLO 22.725 TPHI.FLO SBHN. FLO 177.044 SIGC. FLO 0.000 SIBH. FLO ~OF. FLO -0.035 SDSI.FLO 13.303 BACK.FLO TCAN. FLO 0.000 TCAF. FLO 0.000 TCND.FLO TSCN. FLO 0.000 TSCF. FLO 0.000 INND.FLO TENS.FLO -70.000 GR.FLO 12.430 CCL.FLO DEPT. SBHN. FLO f~4OF. FLO TCAN. FLO TSCN. FLO TENS.FLO 10240 500 52 530 1 095 30873 305 6152 861 -70 000 0 000 254 354 20 045 -257 425 -0 681 0 017 SBHF. FLO TRAT. FLO FBAC. FLO TCFD.FLO INFD.FLO SIGM. FLO 19.154 TPHI.FLO 14.342 SBHF. FLO SIGC.FLO 1.177 SIBH.FLO 72.197 TRAT. FLO SDSI.FLO 0.471 BACK.FLO 334.542 FBAC. FLO TCAF.FLO 17431.180 TCND.FLO 24625.367 TCFD. FLO TSCF. FLO 3473.928 INND.FLO 754.571 INFD.FLO GR.FLO 28.203 CCL.FLO 0.000 122.843 0.000 13.013 -149.850 -0.442 44.405 1.275 83.784 11041.830 661.729 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT . 017 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-MAR-1997 14:18 PAGE: 80 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/03/31 ORIGIN : FLIC TAPE NA~E : 97076 CONTINUATION # : 1 PREVIOUS TAPE : CO~NT · BP EXPLORATION, B-2A, PRUDHOE BAY, API #50-029-20066-01 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE . 97/03/31 ORIGIN : FLIC REEL NAME : 97076 CONTINUATION # : PREVIOUS REEL : CO~4ENT : BP EXPLORATION, B-2A, PRUDHOE BAY, API #50-029-20066-01 Sperry-Sun Drilling Services LIS Scan Utility Mon Mar 10 10:04:34 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Date ,, .! Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/03/10 Origin ................... 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: MWD RUN 2 AK-MW-60088 E. CRIBBS B-02A 500292006601 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 07-MAR-97 MWD RUN 3 MWD RUN 4 AK-MW-60088 AK-MW-60088 E. CRIBBS R. JACKSON RECEIVED OPERATOR WITNESS: D. HEIMS D. HEIMS D. HEIMS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 5 AK-MW-60088 R. JACKSON D. HEIMS REMARKS: MWD RUN 6 AK-MW-60088 R. JACKSON D. HEIMS OPEN HOLE 31 liN 14E 931 1598 68.50 67.00 40.60 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2 THROUGH 6 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY. 4. GAMMA RAY DATA FROM 10057'MD, 8377'TVD TO 10306'MD, 8557'TVD IS PULSED/REALTIME DATA. 5. AFTER THE MUD WAS CHANGED, GAMMA RAY DATA SHIFTED 3.1 AAPI UNITS TO THE RIGHT STARTING AT 10307'MD, 8558'TVD. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12283'MD, 9075'TVD. 8.500 7.000 10383.0 6.000 12283.0 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED G~ RAY. 1. ALL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2 THROUGH 6 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY. 4. GAMMA RAY DATA FROM 10057'MD, 8377'TVD TO 10306'MD, 8557'TVD IS PULSED/REALTIME DATA. 5. AFTER THE MUD WAS CHANGED, GAMMA RAY DATA SHIFTED 3.1 AAPI UNITS TO THE RIGHT STARTING AT 10307'MD, 8558'TVD. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12283'MD, 9075'TVD. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 ~DITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5606.5 12234.5 ROP 5686.5 12286.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR EQUIVALENT UNSHIFTED DEPTH 5605.5 10396 5 10422 5 10424 5 10446 0 10450 5 10455 5 10484 0 10486 5 10489 0 10494 0 10519 0 10520 5 10523 0 10561 5 10580 5 10584 5 10591 0 10594 0 10598.5 10625.5 10688.0 10690.5 10698 0 10699 5 10708 0 10711 5 10725 5 10730 0 10733 5 10734 5 10737 5 10743 0 10745 0 10753 0 10776 5 10801 0 10807 0 10817 5 10882 5 10888 0 11328 0 11330 0 5606.5 10397.5 10423.0 10425.5 10446.5 10451.5 10456.0 10484.5 10486.5 10488.5 10493.5 10519.0 10521.5 10523.5 10566.0 10581.0 10584.5 10592.5 10595.5 10600.5 10629.5 10688.0 10690.5 10695.5 10697.5 10706.5 10711.0 10726.5 10730.0 10734.0 10735.0 10738.5 10743.0 10745.0 10753 0 10778 0 10804 0 10810 0 10820 5 10885 5 10891 0 11329 0 11331 5 11840 11851 11865 11866 11999 12031 12033 12035 12067 12283 $ 11844.0 11855.0 11868 5 11870 0 12003 0 12032 0 12037 0 12040 0 12071 0 12287 0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 MWD 6 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 5685.0 10385.0 10385.0- 10746.0 10746.0 11202.0 11202.0 11496.0 11496.0 12283.0 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 .lin 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 FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 Name Min Max Mean Nsam DEPT 5606.5 12286.5 8946.5 13361 ROP 6.54 1789.25 109.962 13201 GR 9.53 1406.03 69.8804 13257 First Reading 5606.5 5686.5 5606.5 Last Reading 12286.5 12286.5 12234.5 First Reading For Entire File .......... 5606.5 Last Reading For Entire File ........... 12286.5 ?ile Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/10 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 ....... 97/03/10 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5605.5 ROP 5685.5 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAHlW_A PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 10306.0 10385.0 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: 17-JUL-96 MSC VER 1.32 DEP V2.04 / NGP V5.74 MEMORY 10385.0 5684.0 10385.0 39.8 46.0 TOOL NUMBER NGP 159 8.500 8.5 KCL 9.70 72.0 9.4 29000 4.8 .000 .000 .000 .000 67.9 HOLE CORRECTION (IN) : TOOL STANDOFF (IN): .6 EWR FREQUENCY (HZ): REMARKS: RIH w/ DGWD RUN #2 drilled tangent section to TD at 10835' MD, 8614' TVD. POOH to drop ESS multi-shot and run 7" casing. $ 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 .lin 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 GRD MWD 2 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5605.5 10385 7995.25 9560 5605.5 ROP 11.25 1789.25 125.138 9399 5685.5 GRD 24.95 1406.03 88.2343 9402 5605.5 Last Reading 10385 10385 10306 First Reading For Entire File .......... 5605.5 Last Reading For Entire File ........... 10385 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/10 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 ....... 97/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Cormnlent Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10306.5 10694.0 ROP 10385.5 10746.0 $ LOG HEADER DATA DATE LOGGED: 21-JUL-96 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : MSC VER 1.32 DEP V2.04 / NGP V5.74 MEMORY 10746.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10385.0 10746.0 48.2 69.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE TOOL NUMBER NGP 94 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 6.0 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: SHEARDRILL 9.00 44.0 8.4 11000 5.8 .000 .000 .000 .000 58.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .6 REMARKS: RIH w/ DGWD, drill cement and out of shoe, start building angle. Drill to 10746' MD, POOH for bit. $ 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 .liN 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 GRD MWD 3 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10306.5 10746 10526.2 880 10306.5 ROP 6.54 574.81 78.54 722 10385.5 GRD 14.16 304.94 37.8601 776 10306.5 Last Reading 10746 10746 10694 First Reading For Entire File .......... 10306.5 Last Reading For Entire File ........... 10746 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/10 Maximum Physical Record..65535 File 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 ....... 97/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10694.5 11149.5 ROP 10748 . 5 11204.0 $ LOG HEADER DATA DATE LOGGED: 23-JUL-96 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: 71.3 MAXIMUM ANGLE: 82.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ MSC VER 1.32 DEP V2.04 / NGP V5.74 MEMORY 11202.0 10746.0 11202.0 TOOL NUMBER NGP 159 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 6.0 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: VI S CO S . SEAWATER 8.40 61.0 7.6 76O0 11.7 .000 .000 .000 .000 60.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .6 REMARKS: RIH with DGWD, drilled tangent section to 11202' MD. POOH for bit. $ 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 .lin 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 4 FT/H 4 1 68 4 2 GRD MWD 4 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10694.5 11201.5 10948 1015 10694.5 ROP 7.78 328.43 38.8073 907 10748.5 GRD 13.61 104.63 24.2082 911 10694.5 Last Reading 11201.5 11201.5 11149.5 First Reading For Entire File .......... 10694.5 Last Reading For Entire File ........... 11201.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/10 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 ....... 97/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11151.0 11444 . 0 ROP 11204 . 0 11496.0 $ LOG HEADER DATA DATE LOGGED: 24-JUL-96 S O FTWARE 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: 79.9 MAXIMUM ANGLE: 80.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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) : MSC VER 1.32 DEP V2.04 / NGP V5.74 MEMORY 11496.0 11202.0 11496.0 TOOL NUMBER NGP 94 6.000 6.0 VI SCOS. SEAWATER 8.50 44.0 8.6 7900 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: 11.6 .000 .000 .000 .000 60.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .6 REMARKS: RIH with DGWD, drilled tangent section to 11496' MD. POOH for bit. $ 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 .lin 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 5 FT/H 4 1 68 4 2 GRD MWD 5 AAPI 4 1 68 8 3 First Last Name Min Max Mean DEPT 11151 11496 11323.5 ROP 30.14 325.78 64.2461 GRD 9.59 24.21 13.7557 Nsam 691 585 587 Reading 11151 11204 11151 Reading 11496 11496 11444 First Reading For Entire File .......... 11151 Last.Reading For Entire File ........... 11496 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/10 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 ....... 97/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11444.5 12230.5 ROP 11496.5 $ LOG, HEADER DATA DATE LOGGED: S O FTWARE 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: NLAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12282.5 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) : 26-JUL-96 MSC VER 1.32 DEP V2.04 / NGP V5.74 MEMORY 12283.0 11496.0 12283.0 67.4 82.5 TOOL NUMBER NGP 94 6.000 6.0 VI SCOS . SEAWATER 8.50 43.0 8.4 9700 10.6 .000 .000 .000 .000 63.3 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 97/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File c~ - )11 "7¢2(/ B - 02A PRUDHOE BAY I Run 1' 29 - July - 1996 DIFL/ACIZDL/CNIGR Pipe Conveyed WESTERN ATLAS Logging Services 10200 12276 Tape Subfile 2' is type: wiS TAPE HEADER PRUDHOE BAY UNIT -OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CAS ING RECORD RUN 1 6721.0?. BRAD ESARY SEE REd,ARKS B - 02A 500292006601 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 12-AUG-96 RUN 2 RUN 3 31 liN 14E 961 1598 59.72 0.00 40.57 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.000 10385.0 PRODUCTION STRING 6.000 12283.0 REMARKS: DIFL/AC/ZDL/CN/GR. LOGS WITNESSED BY: M. JACKSON & R. GEESAMAN. CIRCI/LATION STOP?ED @ 06:00, 28-JUL-96. PIPE CONVEYED LOGGING. PER E-MAIL NOTE 2?ROM JUMA ATTID (BP), THIS LOG IS THE DEPTH REFERENC]E FOR THIS WELL. CHLORIDES: 7800 MG/L, BARITE: 0. SPOTTED LCM PILL AT 09:00 26-JUL-96. MADE A CLEAN OUT RUN AFTER DRILL PIPE CLOGGED WITH FORMATION MATERIAL AND COULD NOT .CIRCULATE. SPOTTED POLYMER PILL AT 06:00 28-JUL-96. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF I~ASION. NEUTRON LOG PAR/~ETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL SDN 2435 $ depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 10394.0 12182.0 10394.0 12244.0 10394.0 12276.0 10394.0 12208.0 10394.0 12184.0 GR (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS: CURVE SH I FT DATA BASELINE DEPTH LL8 10407.0 10407.0 10423.0 10423.5 10424.5 10425.0 10427.0 10429.0 10434.5 10441.0 10446.0 10446.0 10449.0 10448.5 10451.5 10452.0 10452.5 10454.5 10457.5 10460.5 10460.0 10465.0 10467.5 10470.0 10470.5 10476.5 10480.0 10484.0 10484.5 10486.5 10486.5 10493.5 10494.0 10501.0 10503.0 10519.0 10521.0 10521.5 10521.5 10532.0 10539.0 10545.0 10557.5 10559.0 10564.0 10565.5 10566.0 10570.5 EQUIVALENT UNSHIFTED DEPTH ILD DT RHOB all runs merged; NPHI 10422 . 5 10422 . 5 10422 . 5 10425.5 10429.5 10433.5 10441.5 10451.0 10451.5 10454.5 10457.5 10460.5 10467.5 10470.0 10476.0 10479.0 10484.5 10500.5 10502.5 10520.5 10565.0 10434.0 10446.0 10448.0 10451.0 10465.0 10470.0 10484.0 10 10 10 10 10 10 10 519.0 520.5 531.5 538.5 544.0 557.0 565.0 567.5 571.0 10558.0 10 10 10426.5 10446.0 10452.5 10483.0 10486.5 10521.0 10544.5 no case 10573%5 10577.0 10581.0 10587.0 10589.0 10592.0 10597.0 10600.5 10603.0 10613.5 10614.5 10629.5 10634.5 10644.5 10645.0 10648.0 10659.5 10661.0 10679.0 10679.5 10690.0 10690.5 10694.0 10695.5 10698.5 10708.5 10709.0 10713.5 10726.5 10729.0 10738.5 10743.0 10746.5 10749.5 10758.5 10759.5 10762.0 10771.5 10776.0 10780.0 10785.0 10804.5 10807.0 10810.5 10816.0 10819.0 10826.0 10830.5 10832.5 10841.0 10841.5 10860.0 10862.5 10873.0 10873.5 10885.5 10886.0 10894.5 10897.0 10924.5 10597.0 10644.5 10738.5 10780.0 10807.5 10819.0 10826.5 10841.5 10873.5 10573.5 10577.5 10589.5 10604.0 10614.5 10615.0 10648.5 10661.0 10737.0 10746.5 10759.0 10762.5 10859.5 10861.5 10872.5 10580.0 10629.0 10634.5 10644.0 10658.5 10679.5 10689.0 10693.0 10695.0 10726.5 10749.5 10776.5 10784.5 10819.0 10831.0 10841.5 10885.0 10580.0 10592.0 10629.0 10633.5 10643.0 10659.0 10679.0 10689.5 10695.0 10698.0 10708.0 10713.5 10738.0 10759.0 10771.0 10775.5 10804.0 10816.5 10832.0 10885.0 10894.0 10897.0 10924.0 10586.5 10592.0 10601.0 10678.5 10694.0 10708.5 10729.0 10737.5 10743.0 10759.0 10804.5 10810.5 10826.0 10841.0 10933.-5 10936.0 10953.0 10957.5 10958.0 10960.5 10961.0 10978.0 10990.0 11000.0 11012.5 11024.5 11025.0 11044.5 11075.5 11079.0 11095.0 11095.5 11132.0 11134.5 11157.0 11175.0 11175.5 11182.5 11185.5 11194.5 11197.0 11213.5 11254.0 11285.5 11287.5 11316.5 11329.0 11372.5 11380.0 11445.0 11458.5 11493.5 11544.0 11571.0 11598.5 11628.5 11629.0 11678.5 11680.0 11691.0 11694.0 11720.5 11767.0 11772.0 11781.5 11787.5 11801.0 11803.0 11803.5 11827.0 11840.0 11845.5 11851.0 11855.0 11095.5 11287.0 11787.5 10952.5 10957.0 10958.0 10961.0 11000.0 11024.5 11075.0 11134.5 11175.0 11182.5 11254.5 11316.5 11445.0 11694.0 11803.0 10933.5 10936.0 10960.0 11025.0 11076.0 11079.0 11095.0 11329.5 11372.0 11571.5 11629.0 11803.5 11854.5 15936.0 10978.0 10989.5 11012.0 11044.5 11095.5 11132.5 11157.0 11175.0 11185.0 11194.5 11197.0 11213.5 11329.0 11458.5 11493.0 11544.5 11628.5 11678.5 11680.0 11691.0 11720.5 11767.0 11772.0 11781.5 11800.5 11826.0 11839.0 11095.0 11176.0 11285.0 11329.0 11380.0 11599.0 11628.5 11845.0 11850.5 11854.5 11857.5 11861.0 11864.0 11865.0 11895.0 11901.5 11909.5 11964.5 11975.0 11980.0 12000.5 . 12016.0 12031.0 12036.0 12036.5 12038.5 12043.5 12069.0 12092.0 12098.0 12100.5 12102.5 12103.5 12117.5 12136.5 12137.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DIL SDN 2435 $ REMARKS: 12016.0 11901.0 11979.5 12039.0 12103.5 11861.0 11864.5 11964.0 12016.5 12031.0 12036.0 12136.5 11857.0 11864.0 11895.0 11909.0 11964.0 11974.5 12031.0 12035.5 12043.5 12091.5 12097.0 12100.0 12102.0 12117.5 12138.0 RUN NO. PASS NO. MERGE TOP 1 4 10394.0 1' 4 10394.0 1 4 10394.0 1 4 10394.0 1 4 10394.0 OPEN HOLE portion of MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, CALl, & RB1 WERE SHIFTED WITH R/ROB. FUCT & NUCT WERE SHIFTED WITH NPHI. 11861.0 11865.0 11964.5 12000.5 12016.0 12069.0 12136.0 MERGE BASE 12182.0 12244.0 12276.0 12208.0 12184.0 / ? ?MATCH1. OUT / ? ?MATCH2. OUT / ? ?MATCH3. OUT / ? ?MATCH4. OUT /? ?MATCH5. OUT $ CN : BP EXPLORATION WN : B-02A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) (ALASKA) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units 1 GR BCS 68 1 GAPI 2 DT BCS 68 1 US/F 3 TEND BCS 68 1 LB 4 TENS BCS 68 1 LB 5 LL8 DIL 68 1 OHMM 6 ILM DIL 68 1 OHMM 7 ILD DIL 68 1 OHMM 8 RT DIL 68 1 OHMM 9 DI DIL 68 1 IN 10 SP DIL 68 1 MV 11 MTEM DIL 68 1 DEGF 12 RHOB SDN 68 1 G/C3 13 DRHO SDN 68 1 G/C3 14 PEF SDN 68 1 BN%E 15 CALl SDN 68 1 IN 16 RB1 SDN 68 1 DEG 17 NPHI 2435 68 1 PU-S 18 FUCT 2435 68 1 CPS 19 NUCT 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 57 310 01 1 4 4 57 530 16 1 4 4 57 995 99 1 4 4 57 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 995 99 1 76 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 316 Tape File Start Depth = 12286.000000 Tape File End Depth = 10394.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 75701 datums Tape Subfile: 2 614 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 10200.0 2435 10200.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH NPHI 10230.0 10230.0 10269.5 10269.5 10292.0 10292.0 10301.0 10301.5 10313.5 10314.0 10327.0 10327.0 10356.5 10356.5 10367.0 10366.5 10369.5 10369.5 10373.5 10373.5 10382.0 10382.0 10388.0 10388.5 $ REMARKS: STOP DEPTH 10394.0 10394.0 EQUIVALENT UNSHIFTED DEPTH CASED HOLE portion of MAIN PASS. FUCT, NUCT, TEND, & TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH6. OUT $ : BP EXPLORATION (ALASKA) : B-02A : PRUDHOE BAY : NORTH SLOPE * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units GRCH 2435 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 43 310 01 1 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TEND 2435 68 1 LB 4 6 TENS 2435 68 1 LB 4 4 43 995 99 4 43 995 99 4 43 995 99 4 43 995 99 4 43 995 99 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 Tape File Start Depth = 10394.000000 Tape File End Depth = 10198.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2752 datums Tape Subfile: 3 53 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 4 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10198 . 0 12182 . 5 AC 10384 . 0 12244 . 5 DIFL 10384.0 12276.0 ZDL 10384 . 0 12208 . 5 2435 10198 . 0 12184 . 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIR~TION 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 SWIV CHT MIS MODL GR CN KNJT ZDL TEMP KNJT PCM RB KNJT AC KNJT DIFL $ SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT Z-DENSITY TEMPERATURE KNUCKLE JOINT PULSE-CODE MODUT~TOR RB-SUB KSTUCKLE JOINT BHC ACOUSTILOG KNUCKLE JOINT DUAL INDUCTION 29-JUL-96 FSYS REV. J001 VER. 1.1 600 28-JUL-96 307 29-JUL-96 12283.0 12278.0 10394.0 12276.0 1200.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 1309XA 2435XA 3921XA 2222F~A/2222MA 2806XA 3921XA 3506XA 3975XA 3921XA 1609EA/1603MA 3921XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT): 6.000 10385.0 10394.0 BOREHOLE CQNDITIONS 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): M3~TRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B-02A : PRUDHOE BAY : NORTH SLOPE : ALASKA VISCOSIFIED SEAWATER 8.50 42.0 7.8 7.8 201.0 .435 90.5 .204 201.0 .467 76.1 .000 .0 .541 76.1 .000 .0 THERMAL SANDSTONE 2.65 .000 1.5 * FORMJ~T RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Name Tool Code Samples Units GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMp DIFL 68 1 DEGF ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 60 310 01 1 4 60 520 99 1 4 60 635 99 1 4 60 635 99 1 4 60 636 99 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 17 RB ~ZDL 68 1 DEG 4 18 CNC 2435 68 1 PU-S 4 19 CNCF 2435 68 1 PU-S 4 20 CN 2435 68 1 PU-L 4 21 LSN 2435 68 1 CPS 4 22 SSN 2435 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 760 4 46 631 01 4 43 995 99 4 43 995 99 4 43 890 01 4 43 334 31 4 43 334 30 88 Tape File Start Depth = 12286.000000 Tape File End Depth = 10198.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE .TRAILER **** LIS representation code decoding summary: Rep Code: 68 267821 datums Tape Subfile: 4 848 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 5 is type: LIS FILE HE~ER FILE ~ER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBF~R: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE S~Y VENDOR TOOL CODE START DEPTH GR 11936.0 AC 11998.0 DIFL ZDL 2435 $ 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) : 12023.0 11963.0 11942.0 TOOL STRING (TOP TO BOTTOM) V~NDOR TOOL CODE TOOL TYPE SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT Z-DENSITY TEMPERATURE KNUCKLE JOINT PULSE CODE MODULATOR RB- SUB KNUCKLE JOINT BHC ACOUSTILOG KNUCKLE JOINT DUAL INDUCTION SWIV CP~ MiS MODL GR CN KNJT ZDL ~P KNJT PCM RB KNJT AC KNJT DIFL $ BOREI{OLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : ~ER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: STOP DEPTH 12182.5 12245.0 12276.0 12208.5 12189.0 29-JUL-96 FSYS REV. J001 VER. 1.1 600 28-JI3L-96 2344 28-JUL-96 12283.0 12278.0 10394.0 12276.0 1200.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 1309XA 2435XA 3921XA 2222EA/2222MA 2806XA 3921XA 3506XA 3975XA 3921XA 1609EA/1603MA 3921XA 1503XA 6.000 10385.0 10394.0 VISCOSIFIED SEAWATER 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: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B-02A : PRUDHOE BAY : NORTH SLOPE : ALASKA 8.50 42.0 7.8 7.8 201.0 .435 .204 .467 .000 .541 .000 THERMAL SANDSTONE 2.65 .000 1.5 90.5 201.0 76.1 .0 76.1 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RB ZDL 68 1 DEG CNC 2435 68 1 PU-S 4 4 60 310 01 1 4 4 60 520 99 1 4 4 60 635 99 1 4 4 60 635 99 1 4 4 60 636 99 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 660 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 280 99 1 4 4 46 631 01 1 4 4 43 995 99 1 19 CNCF ~2435 68 ! PU-S 4 20 CN 2435 68 I PU-L 4 21 LSN 2435 68 1 CPS 4 22 SSN 2435 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 129 4 43 995 99 4 43 890 01 4 43 334 31 4 43 334 30 88 Tape File Start Depth = 12286.000000 Tape File End Depth = 11934.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35160 datums Tape Subfile: 5 215 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 6 is type: LIS 96/ 8/12 01 **** REEL TRAILER **** 96/ 8/13 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 13 AUG 96 l:08p Elapsed execution time = 4.89 seconds. SYSTEM RETURN CODE = 0