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HomeMy WebLinkAbout189-0117. 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 12-32 Replace K valve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 189-011 50-029-21910-00-00 13500 Conductor Surface Intermediate Production Liner 9223 80 4400 12763 1019 13454 20" 13-3/8" 9-5/8" 7" 9191 34 - 114 34 - 4434 31 - 12794 12480 - 13499 34 - 114 34 - 3554 31 - 8710 8487 - 9222 13046 , 13124 470 1950 4760 7020 none 1490 3450 6870 8160 12792 - 13140 4-1/2" 12.6# x 5-1/2" 17# 13Cr85/L-80 8708 - 8963 Structural 4-1/2" Baker S-3, 12292 , 8359 4-1/2" K-Valve 12292 , 12423 8359 , 8448 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028331 , 0028330 258 0 6115 0 7028 0 1719 0 386 0 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker FB-1, 12423 , 8448 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 20 - 12392 , 12417 - 12540 20 - 8426 , 8444 - 8529 By Kayla Junke at 1:58 pm, May 10, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.05.10 07:02:35 -08'00' WCB 1-4-2024 RBDMS JSB 051623 DSR-5/10/13 ACTIVITYDATE SUMMARY 4/28/2023 ***WELL S/I ON ARRIVAL*** TAGGED K-VALVE SSSV AT 2,016' SLM (2,030' MD) W/ 3.80" G-RING PULLED 3.81" X-LOCK w/ X EQ SUB & HES K-VALVE (ser # K314A) FROM 2030' MD BRUSHED SSSV X -NIPPLE AT 2030' MD SET 3.81" X-LOCK w/ X- EQ SUB & HES K-VALVE (SER # K-50A 360 PSI @ 60) @ 2030' MD RAN 4 1/2" CHECK SET(good) ***WELL LEFT SHUT IN DSO NITIFIED OF WELL STATUS*** Daily Report of Well Operations PBU 12-32 BRUSHED SSSV X -NIPPLE AT 2030' MD TAGGED K-VALVE SSSV AT 2,016' SLM (2,030' MD) W/ 3.80" G-RING() PULLED 3.81" X-LOCK w/ X EQ SUB & HES K-VALVE (ser # K314A) FROM 2030' MD SET 3.81" X-LOCK w/ X- EQ SUB & HES K-VALVE (SER # K-50A 360 PSI @ 60) @ 2030' MD RAN 4 1/2" CHECK SET(good) Operator Name:2. Development Exploratory Service… 5 … … Permit to Drill Number:189-011 6.50-029-21910-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13500 13454 9191 12292 , 12423 13046 , 13124 none 8359 , 8448 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 110 20" 34 - 114 34 - 114 1490 470 Surface 4400 13-3/8" 34 - 4434 34 - 3554 3450 1950 Intermediate Production 12763 9-5/8" 31 - 12794 31 - 8710 6870 4760 Perforation Depth: Measured depth: 12792 - 13140 feet True vertical depth:8708 - 8963 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# x 5-1/2" 17# 13Cr85/L-80 12540 12292 , 12423 8359 , 8448Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3, 5-1/2" Baker FB-1 Liner 1019 7" 12480 - 13499 8487 - 9222 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 22520095397327 62732770 1786 2734 389 397 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: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon …Plug Perforations …Fracture Stimulate …Pull Tubing … …GSTOR WINJ …WAG …GINJ …SUSP ……SPLUG 16. Well Status after work:Oil 5 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 measured9223 Sundry Number or N/A if C.O. Exempt: 321-197 K-valve 2030 1945 Junk Packer Printed and Electronic Fracture Stimulation Data 5 … … … Install K valve 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: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028331 , 028330 PBU 12-32 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): … Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 10:16 am, Apr 30, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.30 09:12:00 -08'00' Bo York MGR30JUL2021 DSR-4/30/21 RBDMS HEW 4/30/2021 SFD 5/3/2021 ACTIVITYDATE SUMMARY 4/11/2021 ***WELL S/I ON ARRIVAL*** (SSSV maintenance) BRUSH 4-1/2" X-NIPPLE AT 2,030' MD W/ 4-1/2" BRUSH, 3.50" G-RING. SET HES K-VALVE (s/n = K50A - 391 psi @ 60*) ON 4-1/2" X-LOCK AT 2,009' SLM / 2,030' MD. RAN 4-1/2" CHECK SET TO X-LOCK AT 2,009' SLM (Tool sheared indicating good set). PERFORMED SUCCESSFUL DRAW DOWN TEST (DSO witnessed). ***WELL FLOWING ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 4/17/2021 ***WELL FLOWING ON ARRIVAL*** PULL 4.5" XX K-VALVE (TYPE KX14, DOME 391 PSI, SERIAL # K50A, 8 X 1/8" PORTS) SET 4/11/21 SET 4,5" XX K-VALVE (TYPE 22KX14, DOME 360 PSI, SERIAL # K314-A) DRAW DOWN TEST TO 190PSI, GOOD TEST, TURN WELL OVER TO DSO ***WELL FLOWING ON DEPARTURE*** Daily Report of Well Operations PBU 12-32 Operator Name:2. Exploratory Development Service… …5 … Permit to Drill Number:189-011 6.API Number:50-029-21910-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028331 Property Designation (Lease Number):10. 8. PBU 12-32 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 Install K valve … Op Shutdown GAS … GSTOR…WAG … SPLUG … … Abandoned Oil 5 WINJ … Exploratory …Development 5Stratigraphic……Service WDSPL … 12. Attachments: PRESENT WELL CONDITION SUMMARY 13500 Effective Depth MD: 13Cr85 / L-80 11. 4/12/2021 Commission Representative: 15. Suspended … Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity …BOP Test …Mechanical Integrity Test …Location Clearance … Other: Yes …No …Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing … Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9223 Effective Depth TVD:Plugs (MD):Junk (MD): …Other Stimulate Re-enter Susp Well Suspend … …Plug for Redrill …Perforate …Perforate New Pool 12292 , 12423 / 8359 , 8448 No SSSV Installed Date: Liner 1019 7" 12480 - 13499 8487 - 9222 8160 7020 Well Status after proposed work: 16. Verbal Approval: … … …Change Approved Program 34 - 4434 14. Estimated Date for Commencing Operations: BOP Sketch 34 - 114 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3, 5-1/2" Baker FB-1 12792 - 13140 8708 - 8963 4-1/2" 12.6# x 5-1/2" 17#12540 Production 13454 9191 none 13046,13124 34 - 114 470 13-3/8" Contact Phone:(907)564-4672 Date: 4/7/2021 110 149020"Conductor 1950 …GINJ 5 Post Initial Injection MIT Req'd? Yes No … 5 …… … Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4400 3450 Intermediate 12763 9-5/8" 31 - 12794 31 - 8710 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. …No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic … 2337 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. Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.07 19:47:41 -08'00' Bo York By Meredith Guhl at 11:30 am, Apr 16, 2021 321-197 DSR-4/16/21 X DLB 04/16/2021 SFD 4/19/2021, ADL 028330 MGR22APR21 10-404 24 hour notice to AOGCC to witness safety valve performance test within 5 days of stabilized production. Yeption Required? Comm 4/23/21 dts 4/22/2021 RBDMS HEW 4/26/2021 Well Work Prognosis Well Name:12-32 API Number:50-029-21910-00 Current Status:Oil Well Leg:Mainbore Estimated Start Date:April 12th, 2021 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:1890110 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Current Bottom Hole Pressure: 3,217 psi @ 8,800’ TVD Maximum Potential Surface Pressure: 2,337 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary Monthly well test and TIO review indicated an increasing gas FGR over the NFT baseline. During routine well testing the gas lift system was bled down and well flow was observed. The well was shut in and freeze protected. The objective of this intervention is to install a K valve. To test the valve we will open the production choke to common line pressure or divert to a depressurized separator. To reset the valve, the well will be pressured up to above the trip pressure then gradually reopened to the normal operating range. Procedure: 1. MIRU Slick-line 2. RIH and set the subsurface controlled subsurface safety valve. 3. Turn well over to production. 4. Conduct a SVS test within 5 days after stabilized flow. Well Work Prognosis Well Work Prognosis Operator Name:2. Exploratory Development Service… …5 … Permit to Drill Number:189-011 6.API Number:50-029-21910-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028331 Property Designation (Lease Number):10. 8. PBU 12-32 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 Install K valve … Op Shutdown GAS … GSTOR…WAG … SPLUG … … Abandoned Oil 5 WINJ … Exploratory …Development 5Stratigraphic……Service WDSPL … 12. Attachments: PRESENT WELL CONDITION SUMMARY 13500 Effective Depth MD: 13Cr85 / L-80 11. 4/12/2021 Commission Representative: 15. Suspended … Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity …BOP Test …Mechanical Integrity Test …Location Clearance … Other: Yes …No …Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing … Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9223 Effective Depth TVD:Plugs (MD):Junk (MD): …Other Stimulate Re-enter Susp Well Suspend … …Plug for Redrill …Perforate …Perforate New Pool 12292 , 12423 / 8359 , 8448 No SSSV Installed Date: Liner 1019 7" 12480 - 13499 8487 - 9222 8160 7020 Well Status after proposed work: 16. Verbal Approval: … … …Change Approved Program 34 - 4434 14. Estimated Date for Commencing Operations: BOP Sketch 34 - 114 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3, 5-1/2" Baker FB-1 12792 - 13140 8708 - 8963 4-1/2" 12.6# x 5-1/2" 17#12540 Production 13454 9191 none 13046,13124 34 - 114 470 13-3/8" Contact Phone:(907)564-4672 Date: 4/7/2021 110 149020"Conductor 1950 …GINJ 5 Post Initial Injection MIT Req'd? Yes No … 5 …… … Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4400 3450 Intermediate 12763 9-5/8" 31 - 12794 31 - 8710 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. …No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic … 2337 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:20 am, Apr 08, 2021 321-173 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.07 19:47:41 -08'00' Bo York X 24 hour notice to AOGCC to witness safety valve performance test within 5 days of stabilized production. MGR09APR2021 0 DLB 04/08/2021 10-404 DSR-4/8/21 DLB ADL0028330 2337 Yption Required? C 4/9/21 dts 4/9/2021 JLC 4/9/2021 RBDMS HEW 4/9/2021 Well Work Prognosis Well Name:12-32 API Number:50-029-21910-00 Current Status:Oil Well Leg:Mainbore Estimated Start Date:April 12th, 2021 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:1890110 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Current Bottom Hole Pressure: 3,217 psi @ 8,800’ TVD Maximum Potential Surface Pressure: 2,337 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary Monthly well test and TIO review indicated an increasing gas FGR over the NFT baseline. During routine well testing the gas lift system was bled down and well flow was observed. The well was shut in and freeze protected. The objective of this intervention is to install a K valve. To test the valve we will open the production choke to common line pressure or divert to a depressurized separator. To reset the valve, the well will be pressured up to above the trip pressure then gradually reopened to the normal operating range. Procedure: 1. MIRU Slick-line 2. RIH and set the subsurface controlled subsurface safety valve. 3. Turn well over to production. 4. Conduct a SVS test within 5 days after stabilized flow. 24 hour notice for AOGCC to witness the performance test. Well Work Prognosis Well Work Prognosis • v,OF g -,1 y/,"8A THE STATE Alaska Oil and Gas �� LASKA ti�►`�� of Conservation Commission _ A 333 West Seventh Avenue Anchorage, Alaska 99501-3572 V'`�, ' GOVERNOR BILL WALKER g `"�=� Main: 907.279.1433 OA'ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov June 27,2017 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska)Inc. P.O. Box 196612 Anchorage,AK 99519-6612CANNED RE: No-Flow Verification-Correction PBU 12-32 PTD 1890110 Dear Ms. Cocklan-Vendl: On June 6, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-32. The well had a current no-flow determination dated January 31, 2017 allowing it to operate without a subsurface safety valve. The purpose of the June 6 test was to confirm the no-flow status of PBU 12-32 after observing a 20 percent increase in the produced gas- oil ratio. AOGCC's Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-32. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(1)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing,inner annulus,and outer annulus pressures were monitored and recorded during a continuous three- hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree discharged within 3 minutes. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail- safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-32 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. This letter supersedes and replaces the letter previously issued for this well dated June 15, 2017 (corrected permit to drill number). Sincerely, (-6,1, Ja .egg Petroleum Inspection Su ervisor ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDC WellIntegrityCoordinator@bp.com Ryan Daniel, BPXA 11111 • y of Tyr THE STATE Alaska Oil and Gas H is of j\ A K Conservation Commission � __ - ! 333 West Seventh Avenue of 9Pu GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov June 15, 2017 (� 0v ' 19- Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: No-Flow Verification SCANNED N 2 3 201 PBU iiv‘• Ct PTI 189 i1 e' viotto Dear Ms. Cocklan-Vendl: On June 6, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-32. The well had a current no-flow determination dated January 31, 2017 allowing it to operate without a subsurface safety valve. The purpose of the June 6 test was to confirm the no-flow status of PBU 12-32 after observing a 20 percent increase in the produced gas-oil ratio. AOGCC's Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-32. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree discharged within 3 minutes. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-32 demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, 604„,ziE James B. Regg1 Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDC WellIntegrityCoordinator@bp.com Ryan Daniel, BPXA • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg lo//z1,7 DATE: 6/8/2017 P. I. Supervisor FROM: Matt Herrera SUBJECT: No Flow Test Petroleum Inspector PBU 12-32 BPXA PTD 18 I M c'ti 6/6/17: Travelled to PBU Drill site 12 and met up with Lead Operator Ryan Moore and went over the set up for the no-flow test to be performed on PBU 12-32. They had the tubing hard-lined outside to a bleed tank. Also, they had a Crystal pressure gauge on the tree cap (calibration report attached). The well had been open to bleed approximately 9 hours prior to testing/inspection. PBU 12-32 previously passed a no-flow test on 1/23/2017. BPXA's reasoning for performing the no-flow confirmation was due to an increase in gas-oil ratio of approximately 20% based on test separator results for the well. No meter was utilized for today's no-flow test. Instead, BPXA followed the test criteria set in 20 AAC 25.265(I)(1)(B): "well pressure discharged not later than five minutes after a three-hour charted — pressure build-up period' The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:00 0/51/75 0 0 Initial reading; well shut in 9:30 " 0/51/75 0 - 0 Reading Only 10:00 - 0/51/75 0 - 0 Reading; Pressure Check 2 10:30 "0/51/75 0 - 0 Reading Only 11:00 -0/51/75 0 - 0 Reading Only 11:30 -0/51/75 0 - 0 Reading Only 12:00 0/51/75 *Bled to 0 PSI <3 Min ✓ 0 Reading and Bleed - 1 Pressures are T/IA/OA 2 Pressure was checked at a vent point in the hardline; well pressure not bled - Attachments: Crystal Pressure Gauge Calibration 2017-0606_No-FlowPBU 12-32_mh.docx SCANNEDUL 1 72017 Page 1 of 1 . • 0 rl Serial Number: 072716 Contact: D&C Wells Support Bar Code Number: 00149071 Phone#: 5135 Pager#: Tag Number: Upper 073102 Lower 073114 Model Number: NV-4AA-10KPSI-10KPSI Manufacturer: Crystal Engineering Description: nVision Reference Pressure Recorder.Accuracy:30-100%FS-.1%of READ;0-30%FS-.03%FS Facility: Wells Group Technician: Vicki Pate Date Completed: 9/26/2016 Test Equipment: Chandler 19981 Deadweight Teste Tester Accuracy: 0.02% Tester Description: 50 to 10000 psi S/N: 19981 Pin#1= Min. Range: 0 Max Range: 10000 Pin#2= Min. Range: 0 Max Range: 10000 Pin#3= Min. Range: 0 Max Range: 10000 Pin#4= Min. Range: 0 Max Range: 10000 Zero 10% 25% 50% 75% 1 90% 100% #1 Input: 0 1000 2500 5000 7500 9000 10000 #1 Output 0 1003 2507 5012 7516 [ 9018 10014 #2 Input: 0 1000 2500 5000 7500 9000 10000 #2 Output 0 1003 2508 5015 7520 9022 10024 #3 Input: 0 1000 2500 5000 7500 9000 10000 #3 Output 0 1001 2504 5009 7512 r 9014 10008 #4 Input: 0 1000 2500 5000 7500 9000 10000 #4 Output 0 1002 2506 5014 7520 9023 10026 Work Done: Chassis firmware=R080016;CPLD=6;Input#1=A/F Upper mod:UserSpan=1.00000,Firmware=R090009; lnput2- A/L Upper mod:UserSpan=1.00052,Firmware=R090009;hiput#3-A/F Lower Module: U UserSpan- 1.00000,Firmware=R090009;Inpput#4 A/L Lower mod:UserSpan=1.00111,Firmware=R090009; Input values reflect the calculated pressure values of the Chandler weights used to achieve each test point per Chandler certificate#19981-RSA11442-1-HP,dated 4/21/16,traceable to theN,LS.T(684/283503-13) : 0 1002.79 2506,71 5013.45 7519.79 9023;82, 10 026.47 All readings taken on increasing pressure referenced to a Prudhoe Bay,Alaska, local gravity of 9.825959 meters/second squared. Performed byCH2M/Instrumentation CIS 659-8104 PO Box 124 tleli►,r, Prudhoe Bay,AK 99734 411) -4,1"-\11/7;c'4. or r4 g\��\�yy��4 THE STATE Alaska Oil and Gas �t' 7� ufALAsKA Conservation Commission '17-4411114:- ! 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 4 Main: 907.279.1433 OFA SSP Fax: 907.276.7542 www.aogcc.alaska.gov January 31, 2017 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612 RE: No-Flow Verification PBU 12-32 PTD 1890110 SCANNED fop 0 q 2p1 , Dear Ms. Cocklan-Vendl: On January 23,2017 an Alaska Oil and Gas Conservation Commission(AOGCC)Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-32. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-32. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree was 0 psi. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-32 demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, arZee James B. Regg ( / Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDC We IIIntegrityCoordinator@bp.com Ryan Daniel, BPXA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� I`d DATE: 1/23/17 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector PBU 12-32 BPXA , MINED APR 062U17, PTD 1890110 1/23/17: No Flow Test for re-validation based on increased gas production. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:15 AM 0/132/75 N/A N/A Shut in. 14:15 0/129/75 N/A N/A Open well to find zero psi. 1 Pressures are T/IA/OA Summary: After a three-hour build-up the tubing, the well was still at zero psi and produced no gas or fluid during the bleed down. This well exhibits an inability to flow to surface unassisted. Attachments: Gauge calibration certifications (2) Tubing and IA pressure graphs 2017-0123_No-Flow PBU_12-32_gc.docx Page 1 of 1 Ik- IL- 3z (Pr vlIv ) • 1 Z3 - � •7 s Serial Number: 072842 Contact: D&C Wells Support Bar Code Number: 00149051 Phone#: 5135 Pager#: Tag Number: Upper 073245 Lower 073252 Model Number: NV 4AA-IOICPSI lOKPSI Manufacturer: Crystal Engineering Description: 7�t 4A p,� : ,� � �ti j aVision Reference Pressure-kecorder.Accuracy:30-100%FS-.1%of READ;0.30?/oFS-.03%FS Facility: Wells Group Technician: Vicki Pate Date Completed: 9/26!2016 +- Test Equipment: Chandler 19981 Deadweight Teste Tester Accuracy: 0.02% Tester Description: 50 to 10000 psi S/N: 19981 Pin#1= Min. Range: 0 Max Range: 10000 Pin#2= Min. Range: 0 Max Range: 0 Pin #3= Min. Range: 0 Max Range: 10000 Pin #4= Min. Range: 0 Max Range: 0 Zero 10% 1 25% 50% 75% 90% 100% #1 Input: 0 1000 2500 5000 7500 9000 10000 #1 Output 0 1002 2503 5011 7517 9020 10023 #2 Input: 0 0 0 0 0 _ 0 0 #2 Output 0 0 0 0 0 .� 0 0 10000 #3 input: 0 1 1000 J 2500 5000 1. 7500 9000 #3 Output 0 1002 2504 5012 7519 9023 10024 #4 Input: 0 _ 0 l 0 0 0 0 0 #4 Output 0 1 0 0 0 0 0 0 Work Done: Chassis firmware=R080015 updated to 16;CPLD=5;Input#1=A/F-A/L U mod:UserS �. Prm pan=1.00000, Firmware=8090009; Input#3=A/F-A1L Lower mad:UserSpan=1,00000,Firmware=R090009;Input values reflect the calculated pressure values of the Chandler weights used to achieve"each test point per Chandler c rtifcate#19981-RSA1 1442-1-HP traceable to the N.I.S.T(684/283503.13): 0 1002.79 2506.71 5013.45 7519.79 9023.82 10 026.47 All readings taken on increasing pressure referenced to a Prudhoe Bay,Alaska, local gravity of 9.825959 meters/second squared. Perform-d-by CH2MAnstrumentation CIS 659-8104 .dr, PO Box 124 Prudhoe Bay,AK 99734 • 1IZ3 %:=11%:0-4,911f4 4:443:"...11;;;i6lotik"'itir'41:247f:''',.:-:li'A'::.---:.**-:::4'):it'ttii,a,!k''''''''*igi.14-:.:,,aiii--s'. 4.'"Ilit''''',: e.;::::,;:1,,,,,,i1,'„4 .%),V.,:%1.3i;!'..1,.:%.,::Oallilip-;*-allijairliren, ,,ilrim „lin*';','''.7.IF Iffr.-, 14k,, . ,:.-1 kL.4': ,T.:4";Y: L2'.:1,,,,,„:-•,..,-.N:;,,,,,,,.. t=a' - - 17. .,, o b,;; tl'Y ia„ -awe 4Mwl kr ''- '-7''' . Serial Number: 072722 - Contact: D&C Wells Support Bar Code Number: 001-1',07.5 Phone#: 5135 Pager#: Tag Number: Upper 073124 Lower 073143 Model Number: NV-4AA-10KPSI-10KPSI Manufacturer: Crystal Engineering Description: -1-i.' ,- /rucuc5 r'ress46{c,j� `uViston Referepce Pressureitt eetdo AcctrCacy:30-t00'I%FS-J%of READ;0730%FS. 0 °f%F ' 'N ,,, i Facility: Wells Group Technician: Vicki Pate Date Completed: 10/31/2016 Test Equipment: Chandler 19981 Deadweight Teste Tester Accuracy: 0.02% Tester Description: 50 to 10000 psi S/N: 19981 Pin#1= Min. Range: 0 Max Range: 10000 Pin#2= Min. Range: 0 Max Range: 10000 Pin#3= Min. Range: 0 Max Range: 10000 Pin#4= Min. Range: 0 Max Range: 10000 Zero 10% 25% 50% 75% 90% 100% #1 Input: I 0 ( 1000 - 2500 5000 7500 9000 10000 #1 Output 0 1003 2505 5007 7515 9017 10018 #2 Input: 0 1000 2500 i 5000 7500 9000 , 10000 #2 Output 0 - 1004 - 2508 5013 7520 9024 10023 #3 Input: 0 1000 - 2500 5000 7500 9000 10000 #3 Output 0 1002 - 2504 5006 7515 9017 10018 #4 Input: 0 1000 - 2500 5000 7500 9000 10000 #4 Output 0 - 1003 - 2507 5013 7520 9024 10023 Work Done: Chassis firmware=8080015,updated to'16;CPLD.6;Input#I" Upper mod UserSpatt l 00010; 4 Firt:rtrrvar�8090009;',Input#2-A/L Upper'mod UserSpan 1`.00061; "tinware 809 OO9;btpr #=Al Lower"x` Module:Userspan=1.00000,Firmware!R090009;lnput#td A/L Lower mod:UserSpant=�l O0(It;lc Flnnware= RI),o'i t:*; Input values reflect the calculated pressure values cif#te Chandler=cweights;used t°achieveeach point per Chandler certificate#19981!RSAI 1,4424-1�iP,dated 4/21/16,traceable to the N.LS (6841283$03 , 13) . 0 100279 2506,71 5013,45- ,7519.79,,=9023,82 1002 :47 u= i� All readings taken on increasing pressure referenced to a Prudhoe Bay,Alaska, local gravity of 9.825959 meters/second squared. Perfo by CH2M/Instrumentation CIS 659-8104 4101 / PO Box 124 4 r ' Prudhoe Bay,AK 99734 • • 0 l 04 .c. 0 1 q21 0 is - $. N s•1 0 I-I- t z N M N d 0 %ra 6?9 4... c, n ?i t OI N- D d O _0) R d i"S 00 f0 c., Cop r� 3 5 ✓ o -Ja m J • gn. I ',9 c4) — N Oc O Q L (1)' — O V N , M a N 0 E ~ ,.• --.-- 0 = d COd ia 'c c000 • • - d2 V. 0 oF• 0 si( . 0 �Q ze, o I • R i.1v N N N O a— .+ M a(7) COo Cl_ C - d2. E 9�l 0 d To U co a`> O s. $ Moen W o -JO- W J d kr- 43 0ic. 9 rt N `. O = o 0 j N O. o $ Ce o O o O O O o O O O O �p I ,> N CO CO V N0 CO CO V N 0,• 1 O 00 N _a) ya a _. a O r CZ!..- E T 21° ia « co Z1-) m .E C1 yoD .vof 7,4 ��\�yyy� � THE STATE Alaska Oil and Gas F�" i�a Of A LAsKAL Conservation Commission t tt-_ 333 West Seventh Avenue � ;,'�—� C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov October 24, 2016 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612 RE: No-Flow Verification 20'17,PBU 12-32 SCANNED KVKA:' 12i 1 `, PTD 1890110 Dear Ms. Cocklan-Vendl: On October 16,2016 an Alaska Oil and Gas Conservation Commission(AOGCC)Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-32. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-32. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree bled to zero within 3 minutes. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-32 demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, �n4Aked :71-Ree? James B. Regg Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDCWelllntegrityCoordinator@bp.com Ryan Daniel, BPXA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regge iofr4,it, DATE: Sunday, October 16, 2016 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector PBU 12-32 BP Exploration Inc. PTD 1890110 Sunday, October 16, 2016: I witnessed the No Flow verification for BP Exploration's well PBU 12-32 in the Prudhoe Bay Unit. - I met Ryan Moore (BP well integrity engineer) on location for the test. Mr. Moore - explained that the Gas to liquid ratio had increased calling for another No-Flow test. The - details are contained in the table below. Note that the time column is in chronological order. There was no flow observed from the well in the open top tank. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 0:00 0/132/78 - 0 0 Start recorder 09:59 A.M. 0:05 0/131/88 S/I S/I Shut Tubing to tank block valve. 3:05 2/131/88 - S/I S/I Open tubing to tank block valve 3:06 2/131/88 - -- -- Venting tubing to tank 3:07 1/131/88 -- -- Venting tubing to tank - 3:08 0/131/88 - -- -- No flow observed 3:09 0/131/88 - -- -- No flow observed 3:10 0/131/88 -- -- No flow observed, S/I block valve 3:06 0/131/88 - -- -- No buildup observed. . 3:07 0/131/88 - -- -- No buildup observed. - 3:08 0/131/88 - -- -- No buildup observed. - 3:09 0/131/88 - -- -- No buildup observed. - 3:10 0/131/88 Conclude test. - 1 Pressures are T/IA/OA Summary: I witnessed the No Flow test for BPX well PBU 12-32 in the Prudhoe Bay Field. It meets the criteria set forth for this type test. - Attachments: None scANNE® APR 0 7 Z01? 2016-1016_No-Flow_PBU_12-32_1g.docx 01/25/2007 Schluß1bel'gør NO. 4125 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 9 17s¿j-O { ( Field: Prudhoe Bay BL CI CD Well Job# Loa Description Date o or P2-37A 11491392 MEM PROD PROFILE 11/15/06 1 Y-23B 11418299 MEM PROD PROFILE 09/06/06 1 NK-07A 11588698 MEM GLS 12/21/06 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22/06 1 DS 09-32 11555530 INJECTION PROFILE 12/16/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12/06/06 1 S-02Ä 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFLlLDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L 1 11588700 MEM PROD PROFILE 12/23/06 1 E-11 B 11434757 DSI 10/24/06 1 E-11 B 11434760 DSI 10/29/06 1 E-11 B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 G-14A 11485777 SCMT 11/27/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. SCANNED JAN 3 0 2007 Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: '\ . . ~ I STATE OF ALASKA .. /,7M7 ALAS OIL AND GAS CONSERVATION COMr210N REPORT OF SUNDRY WELL OPERATIONS REC:EIVED '\ ,.;,,,,_.,.;.,,; 1 0 ZOO? ~ 1. Operations Performed: '" "1111. o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 189-011 ./ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21910-00-00 / 7. KB Elevation (ft): 74' / 9. Well Name and Number: PBU 12-32 / 8. Property Designation: ADL 028331 j 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool .I 11. Present well condition summary Total depth: measured 13500 . feet true vertical 9223 feet Plugs (measured) None Effective depth: measured 13454 feet Junk (measured) 13046 true vertical 9191 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4434' 13-3/8" 4434' 3554' 3450 1950 Intermediate Production 12793' 9-5/8" 12793' 8709' 6870 4760 Liner 1019' 7" 12480' - 13499' 8487' - 9222' 8160 7020 SCANNED JAN 1 1 2007 Perforation Depth MD (ft): 12792' - 13140' Perforation Depth TVD (ft): 8708' - 8963' 4-1/2",12.6# x 5-112",17# 13Cr80 / L-80 12540' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer; 9-518" x 5-1/2" Baker 12292'; 12423' 'FB-1' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BB 1 1 Treatment description including volumes used and final pressure: Cut and pull tubing from 12377'. Cut and pull 9-5/8" casing from 1802'. Run 9-5/8" tieback to surface and cement with 115 Bbls Class 'G' (646 cu ft /557 sx). Run new 4-1/2" Chrome tubing to 12421'. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 363 877 5,471 1,670 233 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Service ~ Daily Report of Well Operations o Exploratory ~ Development 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 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 Howard West, 564-5471 306-352 Printed Name Terrie Hubble Title Technical Assistant Signature ~ !I^~ ~ M-0<... Date Ol/lO/o7 Prepared By Name/Number: Phone 564-4628 Terrie Hubble, 564-4628 . . . Ion Form 10-404 Revised 04/2006 RIG ì~AL ! \ \ -0, \\. Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11 /25/2006 12/1 5/2006 Spud Date: 2/15/1989 End: 11/28/2006 15:00 - 20:30 5.50 MOB P PRE PJSM with all personnel involved. Move Mud Pump #2 Complex, Move Cuttings tank and Generator #4. Move Rig off Well 12-18 onto pad. Remove BOP stack from pedestal, install rear boosters. Move around pad to Well 12-32. Remove boosters and set BOP stack onto pedestal. Wait on security from 16:30 to 18:30 hrs. 20:30 - 21 :30 1.00 MOB P PRE Check pressure on well 0 pressure on tree and 0 pressure on IA. Spot rig over Well 12-32. Place double mats under substructure and level rig. 21 :30 - 00:00 2.50 MOB P PRE Lay Herculite liner and spot Cuttings tank, Generator #4, and Mud Pump #2. RlU Mud Pump #2, RlU rig floor and cellar. Install secondary annulus valve and take on heated seawater. Rig accepted at 22:00 hours 11/29/2006 00:00 - 00:30 0.50 KILL P DECOMP RlU circulating manifold and lines to well. 00:30 - 01 :30 1.00 KILL P DECOMP RlU DSM Lubricator and pull TWC. 0 pressure on tubing, 0 pressure on IA. Install pump in sub on tree. 01 :30 - 02:30 1.00 KILL P DECOMP Pressure test all surface lines to 3,500 psi. 02:30 - 05:00 2.50 KILL P DECOMP Pump 100 bbls of 120 degree seawater down IA taking returns up tubing through choke manifold. Recovered appx. 40 bbls of diesel freeze protect. Line up and pump down tubing taking returns through choke manifold. Pump a 40 bbl high vis safe clean sweep followed by 900 bbls of 120 degree seawater. 8.5 bpm with 1,000 psi pump pressure. 05:00 - 06:00 1.00 KILL P DECOMP RID pump in sub on tree and Cameron install TWC. 06:00 - 07:30 1.50 WHSUR N SFAL DECOMP Pressure Test TWC to 3500 psi - failed. Leak by on TWC. Call Out DSM Lubricator. 07:30 - 09:00 1.50 WHSUR P DECOMP P/U DSM Lubricator and Pull TWC. Inspect TWC and found rubber O-ring seemed loose. Installed new TWC. UD Lubricator. 09:00 - 10:30 1.50 WHSUR P DECOMP Attempt to test TWC from above with Test Pump. Found pressure by pass leaking on pop off. Rig up hose from mud pump and test TWC to 3500 psi above for 10 mins and 1000 psi below for10 mins. - Good Tests. 10:30 - 11 :00 0.50 WHSUR P DECOMP Rig Down and Blow Down Lines and Hoses for Test Equipment. 11 :00 - 13:00 2.00 WHSUR P DECOMP N/D Tree and Adapter Flange. Inspect hanger threads and test with 4-1/2" TC-II XO. 13:00 - 15:30 2.50 DECOMP N/U 13-518" Spacer Spool to Wellhead and 13-5/8" BOP Stack w/3-1/2" by 5" VBR's. 15:30 - 18:00 2.50 DECOMP RlU BOPE Test Equipment and Test BOPE. 250 psi Low and 3500 psi High. Hold each test for 5 minutes. Witness of test waived by John Crisp of AOGCC. Test witnessed by Doyon Toolpusher and BP WSL. 18:00 - 20:30 2.50 RREP DECOMP Trouble shoot and re-dress test pump. 20:30 - 00:00 3.50 DECOMP Test BOPE, Choke Manifold, Floor Valves, Upper IBOP, Lower IBOP, Choke Line Valves and Kill Line Valves to 250 psi Low and 3500 psi High. Hold each test for 5 minutes. Witness of test waived by John Crisp of AOGCC. Test witnessed by the Doyon Toolpusher and BP WSL. No Failures. 11/30/2006 00:00 - 02:30 DECOMP Test BOPE, Choke Manifold, Floor Valves, Upper IBOP, Lower IBOP, Choke Line Valves and Kill Line Valves to 250 psi Low and 3500 psi High. Hold each test for 5 minutes. Witness of test waived by John Crisp of AOGCC. Test witnessed by Printed: 12/18/2006 11 :26:42 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11 /25/2006 12/15/2006 Spud Date: 2/15/1989 End: 17:30 - 23:30 23:30 - 00:00 6.00 CLEAN P 0.50 CLEAN P Doyon Toolpusher and BP WSL. No Failures. RlU DSM lubricator and lubricator extension. Pull Cameron TWC, DSM rolled threads on TWC running tool on first attempt. Changed running tool and pulled TWC with no further problems. UD lubricator and exrension. MIU TC II landing joint and screw into hanger. Back out lock down screws. Pull McEvoy hanger to rig floor. Up weight 158,000#. Circulate bottoms up 13 bpm with 230 psi pump pressure. Monitor well. UD hanger, RlU compensator and tubing handling equipment. PJSM with all involved parties. POOH laying down 4 1/2" 12.6#, 13CR85 Fox tubing. Using compensator and putting thread protectors on all tubing layed down. Service Top Drive and Drawworks. Continue POOH laying down 4 1/2" 12.6#, 13CR85 Fox tubing. Using compensator and putting thread protectors on all tubing layed down. Recovered 5 GLM's, 2 X Nipple assemblies, 385 joints of tubing and a 7.12' cut joint. Cut was flared all the way around and was fully cut. RID tubing handling equipment. Clear rig floor. Install Wear Bushing. ID on Wear Bushing 9 1/8" M/U BHA #1 , 8.5" MM Packer Mill w/ 3.625" Nose, 3 x 7" Boot Baskets, XO, 6.25" Fishing Jar, XO, 9 x 6.25" DC's XO. Total BHA = 310.81' RIH w/4" DP, P/U 1 x 1 from pipe shed. Safety Stand Down. "Personal Commitment to Safety " Attendace by WSL's, Toolpushers, Rig Crew, Mud Engineer, Fishing Hand, Support Crew, Doyon Safety, BP Safety, Doyon Field Suprv., & BP Director of Drilling and Wells Gary Christman. DECOMP RIH w/4" DP, P/U 1 x 1 from pipe shed. DECOMP M/U Top Drive and Establish Parameters. Up weight 217,000#, Down Weight 135,000#, Rotating weight 170,000#. 80 rpm with9,000 ftllbs torque. Tag top of 41/2" stub at 12,282', 7 bpm with 1,830 psi pump pressure DECOMP MiII41/2" tubing stub and packer from 12,282' md. WOB 3000 - 20,000#, RPM 80 - 120 rpm with 10,000 - 18,000 ft /Ibs of torque. Milled 3' and the packer fell 3'. Lost 37 bbls of seawater to well. Packer appears to be spinning. Set 20,000# down weight on packerto set packer, continue milling packer. Fluid loss - 1 bpm at a pump rate of 7 bpm and 2110 psi. Continue to mill packer down to 12291' md. Small amount of rubber in returns. Pump 40 bbl high visc sweep and circulate at 12 bpm and 3200 psi. Large volume of rubber chunks and pieces as well as metal shavings seen w/ sweep. Shut down pumps and monitor well for flow. Break off top drive and blow down same. POOH and Stand Back DP in Derrick. B/O and UD Packer Mill BHA. Boot Baskets contained -8 gallons of metal shavings. Mill showed moderate wear on the face and strong wear along the OD. 04:00 - 04:30 0.50 PULL P DECOMP 04:30 - 05:00 0.50 PULL P DECOMP 05:00 - 05:30 0.50 PULL P DECOMP 05:30 - 06:30 1.00 PULL P DECOMP 06:30 - 00:00 17.50 PULL P DECOMP 12/1/2006 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 03:00 2.50 PULL P DECOMP 03:00 - 04:00 1.00 PULL P DECOMP 04:00 - 04:30 0.50 CLEAN P DECOMP 04:30 - 06:00 1.50 CLEAN P DECOMP 06:00 - 12:00 6.00 CLEAN P DECOMP 12:00 - 17:30 5.50 CLEAN P DECOMP 12/2/2006 00:00 - 06:00 6.00 CLEAN P 06:00 - 08:00 2.00 CLEAN P DECOMP 08:00 - 09:00 1.00 CLEAN P DECOMP 09:00 - 09:30 0.50 CLEAN P DECOMP 09:30 - 14:30 5.00 CLEAN P DECOMP 14:30 - 15:30 1.00 CLEAN P DECOMP Printed: 12/18/2006 11:26:42AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11 /25/2006 12/15/2006 Spud Date: 2/15/1989 End: 12/2/2006 15:30 - 16:30 1.00 CLEAN P DECOMP M/U BHA #2; Bowen Itco Spear wI 3.885 Grapple, 3 x 7" Boot Baskets, 6-1/4" Bowen Bumper Sub, 6-1/4" Fishing Jar, 9 x 6-1/4" DC's. Total BHA = 321.83' 16:30 - 21 :00 4.50 CLEAN P DECOMP RIH wI DP from Derrick. Break Circulation at 4,000' and 8,000'. 21 :00 - 21 :30 0.50 CLEAN P DECOMP Establish parameters, Up weight 229,000#, Down weight 132,000#, Rotating weight 176,000#. 20 rpm with 7,000 ftllbs of torque. 3 bpm at 275 psi pump pressure. Tag at 12,292'. Saw 30 psi pump pressure increase. Set 20,000# down and P/U to 275,000#, Fire Jars, P/U to 300,000#, Moved up 1-2' and set, Work string pulling up to 350,000# with no drag going down. Work up 20',15,000 - 25,000# drag coming up. Complete loss of returns. 21 :30 - 22:30 1.00 CLEAN P DECOMP Lost returns, line up and fill hole at 10 bpm. Minimal returns after 550 bbls seawater pumped away. Establish Loss rate of 600 bph. Pumped a total of 625 bbls of seawater. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH and Stand Back DP in Derrick. Packer assembly dragging with 15,000 - 25,000# overpull. Filling with 60 bhp plus double pipe displacement. 12/3/2006 00:00 - 03:30 3.50 CLEAN P DECOMP POOH and Stand Back DP in Derrick. Packer assembly dragging with 15,000 - 25,000# overpull. Filling with 60 bph plus double pipe displacement. 03:30 - 04:30 1.00 CLEAN P DECOMP Stand back 61/4" DC's and UD spear assembly. 04:30 - 06:30 2.00 CLEAN P DECOMP UD Packer and tailpipe assembly. Recovered Baker S-3 Packer, 5 Tbg Pup Jts, 1 X Nipple, 1 XN Nipple wI Plug, 1 Joint of Tbg, and 1 WLEG. Heavy scars on the outside of the packer indicate something dragging up hole. Deep gouges on WLEG showing that it was driven down on top of something. Filling wI 80 bbls per Hour. 06:30 - 07:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor 07:00 - 07:30 0.50 CLEAN P DECOMP Gather Up subs for next BHA 07:30 - 08:30 1.00 CLEAN P DECOMP Service Draw Works, Iron Rough Neck, and Replace Burned Out Light I Fixture in Derrick. 08:30 - 10:00 1.50 CLEAN P DECOMP MIU BHA #3; 8-3/8" Mill wI 4-3/4" Carbide Nose Section, 9-5/8" Casing Scraper, 3 x 7" Boot Baskets, Bumper Sub, Jars, 9 x 6-1/4" DC's. Total Length = 324.26' 10:00 - 15:30 5.50 CLEAN P DECOMP RIH wI BHA#3 on DP from derrick. Continue to fill hole with double displacement while RIH and pumping a drill pipe volume every 25 stands in the hole. Fluid Level holding around 2000 ft. 15:30 - 16:30 1.00 CLEAN P DECOMP Establish Parameters; Up Wt = 255,000 Ibs, Dw Wt - 131,000 Ibs, Rot Wt = 180,000 Ibs wI 80 rpm's and free torque of 14,500 ft-Ibs. Pump rate = 3 bpm at 30 psi. With pumps off and no rotation slack off and tag top of tbg stub at 12379'. P/U establish pumps and rotation, SIO and set down 4,000 Ibs and 1,500 ft-Ibs torque. Let mill off. P/U and tag again wI no rotation or pumps. Tag at 12380'. 16:30 - 21:30 5.00 CLEAN P DECOMP Break off and blow down top drive. POOH and rack back DP. Double Displace out of hole wI an additional 60 bbl per hour. 21 :30 - 23:00 1.50 CLEAN P DECOMP UD BHA #3, Mill and Scraper Assembly. Clear and clean rig floor. Feed Well with 20 bbls 115 mins. 23:00 - 00:00 1.00 CLEAN P DECOMP M/U HES 95/8" Model3L RBP. 12/4/2006 00:00 - 06:00 6.00 CLEAN P DECOMP RIH with HES 9 5/8" Model 3L RBP on DP from Derrick. Fill wI Double Displacement and additional 60 bbls pr hour. Printed: 12/18/2006 11:26:42 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/25/2006 12/15/2006 Spud Date: 2/15/1989 End: 12/412006 06:00 - 08:00 2.00 CLEAN P DECOMP Obtain parameters; Down Wt = 120,000 Ibs, Up Wt = 252,000 Ibs. Attempt to set at 12312'. Make Multiple Attempts. Make over 16 LH turns at surface trying to get turns down. 08:00 - 09:30 1.50 CLEAN P DECOMP Consult Town Try again at 9000'. P/U 2 joints and RIH and Tag up on Tbg Stub to confirm have tool on. POOH to 9000' 09:30 - 10:30 1.00 CLEAN P DECOMP Obtain parameters; Down Wt = 106,000 Ibs, Up Wt = 197,000 Ibs. Attempt to set at 12312'. Make Multiple Attempts. Make over 16 LH turns at surface trying to get turns down. 10:30 - 15:00 4.50 CLEAN P DECOMP POOH to Inspect RBP 15:00 - 16:00 1.00 CLEAN P DECOMP Plug had released from running tool. Consult with Town. Decide to RIH and Fish Bridge Plug. Make Repairs on Iron Rough Neck, Inspect Saver Sub, Perform Work Orders. 16:00 - 16:30 0.50 CLEAN P DECOMP M I U RBP Running Tool and DC's 16:30 - 21 :30 5.00 CLEAN P DECOMP RIH w/4"DP from 302' to 12,376'. Up weight 262,000# Down weight 119,000#. 21 :30 - 22:00 0.50 CLEAN P DECOMP P/U single joint of 4" DP. Latch onto HES RBP at 12,380'. P/U and set top of HES RBP at 12,333'. Set 20,000# on RBP, Pull 20,000# on RBP to insure plug is set. Release from RBP. Set back on RBP to verify RBP is set. 22:00 - 00:00 2.00 CLEAN P DECOMP Circulate bottoms up at 10 bpm with 2,430 psi. Returns at surface with 80 bbls pumped. 12/5/2006 00:00 - 00:30 0.50 CLEAN P DECOMP RlU Circulating head. Pressure up and test HES 9 5/8" RBP to 2,000 psi for 15 minutes. Good test. 00:30 - 05:00 4.50 CLEAN P DECOMP POOH wI 4" DP from 12,333' to 277' 05:00 - 06:00 1.00 CLEAN P DECOMP Stand back 6 1/4" DC's and inspect and UD HES RBP running tool. Clear and Clean Rig Floor. 06:00 - 10:30 4.50 CLEAN P DECOMP Safety Stand Down. 10:30 - 11 :00 0.50 CLEAN P DECOMP Nipple Down Riser 11 :00 - 12:00 1.00 CLEAN P DECOMP Nipple Up Shooting Flange 12:00 - 17:00 5.00 CLEAN N WAIT DECOMP Wait on SWS E-Line to arrive on location. 7" BOP's in use on another job. Add .46 line BOP Rams and Hydro Test prior to arriving on location. 17:00 - 20:30 3.50 CLEAN P DECOMP E-Line on Location. Spot Unit and Equipment to be used on Rig Floor. 20:30 - 23:00 2.50 CLEAN N SFAL DECOMP Trouble Shoot Wire Line Tools, Noise on Sonic, C/O Same. 23:00 - 00:00 1.00 CLEAN P DECOMP RlU and Test Surface Equipment to 2,000 psi 12/6/2006 00:00 - 06:30 6.50 CLEAN P DECOMP RIH w/USIT and Corrosion. Top of Cement at 1,860'. 06:30 - 07:30 1.00 CLEAN P DECOMP RID US IT Logging Assembly. 07:30 - 15:00 7.50 CLEAN N DECOMP RlU 40 arm caliper assembly. Problems with batteries, PDS returned to shop for repairs, 15:00 - 16:00 1.00 CLEAN N DECOMP Reprogram and MIU and test PDS tool. 16:00 - 22:00 6.00 CLEAN N DECOMP RIH w/PDS, GR-CCL logging tools to 12,300' and log up. PDS operator observed arms not in proper position to obtain data, when tool was at surface. After RID tool checked and confirmed No Data Obtained. 22:00 - 00:00 2.00 CLEAN P DECOMP RlU and RIH with string shot to 1,797'. Made Shot POOH. Junk left in hole, Sled Shoe and Extension approx 12 - 14" Long and 1.5" wide and 1.5" Thick. 12/7/2006 00:00 - 00:30 0.50 CLEAN P DECOMP RID SWS Lubricator Extendsion, Pump In Sub, BOPs and Pack Off. 00:30 - 01 :30 1.00 CLEAN P DECOMP N/D Shooting Flange, N/U Flow Riser. 01 :30 - 02:30 1.00 CLEAN P DECOMP MIU RBP Running Tool, RBP and 3 stand DC. 02:30 - 03:00 0.50 CLEAN P DECOMP RIH w/RBP to 1,400' Printed: 12/18/2006 11 :26:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11 /25/2006 12/15/2006 Spud Date: 2/15/1989 End: 12/7/2006 03:00 - 03:30 0.50 CLEAN P DECOMP Obtain Parameters Down Wt = 72,000#, Up Wt = 72,000#, Rotate to the right 1/2 turn, Torque indicates RBP is attached to running tool. 03:30 - 04:00 0.50 CLEAN P DECOMP Continue to RIH w/RBP to 2,800'. 04:00 - 04:30 0.50 CLEAN P DECOMP Obtain Parameters, Up Wt = 86,000#, Down Wt = 76,000#, Set top of RBP at 2,800', confirmed w/15,000# Down Wt. 04:30 - 05:30 1.00 CLEAN P DECOMP RlU and Test RBP to 2,000 psi f/15 minutes, good test. BID Surface Lines 05:30 - 06:30 1.00 CLEAN P DECOMP Pump 20 bbl Hi-Vis Sweep followed by 200 bbl of 9.8 ppg brine at 9 BPM w/500 psi. 06:30 - 07:30 1.00 CLEAN P DECOMP POOH and Stand Back DP and Collars. 07:30 - 08:00 0.50 CLEAN P DECOMP UD RBP Running Tool. 08:00 - 10:00 2.00 CLEAN P DECOMP P/U 7" Lub Ext and set in rotarty table. Dump in 2200# of Sand. -50' in 9-5/8" 47# casing. 10:00 - 11 :00 1.00 CLEAN P DECOMP UD 7" Lub Ext and Pull Wear Ring. 11 :00 - 13:30 2.50 CLEAN P DECOMP N/D Flow Riser. Split Stack and N/D 13-3/8" Spacer Spool. 13:30 - 14:30 1.00 CLEAN P DECOMP N/U BOP's to Tubing Spool and N/U Flow Riser. 14:30 - 15:00 0.50 CLEAN P DECOMP Rig Up BOP Test Joint and Equipment. 15:00 - 00:00 9.00 CLEAN P DECOMP Weekly BOP Pressure Test. Problems with Test Plug Leaking. Pull and re-seat twice. Call out new test plug. Set new test plug, and continued BOP test. Pressure tested 250 psi Low Test and 3,500 psi High Test held for 5 minutes. AOGCC representitive Chuck Sheave Waived Witness of BOP Test. Test Witnessed By BP WSL and Doyon Tool Pusher. 12/8/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Continued to test BOPE. Weep Noticed on the top of Tubing Spool and another between Blind Rams and Mud Cross. Re-Torqued Flange Bolts and Continued Testing. 00:30 - 01 :00 0.50 CLEAN P DECOMP RID test equipment and blow down Choke Manifold and Kill line. 01 :00 - 01 :30 0.50 CLEAN P DECOMP Run Wear Ring. 01 :30 - 03:00 1.50 CLEAN P DECOMP P/U 9 5/8" CSG Cutter w/3.5" Knifes, Adjust Knifes, RIH 3 Stds Drill Collars. 03:00 - 03:30 0.50 CLEAN P DECOMP RIH w/Drill Pipe to 1,500', M/U Top Drive. 03:30 - 06:30 3.00 CLEAN P DECOMP Cut and Slip 1,700' Drilling Line. New Spool Long Cut. 06:30 - 07:00 0.50 CLEAN P DECOMP Continue to RIH to 1730'. Establish Parameters, Up Wt = 75K Ibs, Dn Wt = 75k Ibs. Free Torque =3k ft-Ibs at 80 rpm's. Locate 9-5/8" casing collar at 1802'. 07:00 - 07:30 0.50 CLEAN P DECOMP Pull Up hole and place cutters at 1787'. Cut Pipe w/3-5K torque at 80 rpms, and 1000 psi pump pressure at 5 bpms. Cut took 12 mins to complete. Confirmation of cut, OA pressure up to 250 psi. 07:30 - 09:00 1.50 CLEAN P DECOMP Circulate 40 bbl High Visc Detergent Sweep and Chased with 150 bbls of 9.8 ppg Brine, 120 degree fluid. Pump rate 2-5 bpm. Rate at 5 bpm with choke full open at 1200 psi. 09:00 - 09:30 0.50 CLEAN P DECOMP Monitor well and let fluids swap. 09:30 - 10:30 1.00 CLEAN P DECOMP Circulate 130 bbls of 120 degree 9.8 brine @ 4.5 bpm 970 psi wI choke full open. 10:30 - 11 :00 0.50 CLEAN P DECOMP Monitor OA and Drill String for flow, open bag and monitor again. 11 :00 - 12:00 1.00 CLEAN P DECOMP POOH, Stand Back DP and Collars. UD BHA. 12:00 - 13:00 1.00 CLEAN P DECOMP Pull Wear Ring and Clear and Clean rig Floor. 13:00 - 13:30 0.50 CLEAN P DECOMP M/U 9-5/8" Casing Spear. 13:30 - 14:30 1.00 CLEAN P DECOMP RIH and Engage Mandrel hanger. PI U Hanger Break Free at Printed: 12/18/2006 11:26:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11 /25/2006 12/15/2006 Spud Date: 2/15/1989 End: 12/812006 13:30 - 14:30 1.00 CLEAN P DECOMP 175,000 Ibs and Pull to Floor at 140,000 Ibs. CBU at 8 bpm and 850 psi. 14:30 - 20:00 5.50 CASE P DECOMP POOH and UD 9-5/8" Casing. 175,000# to break over, 140,000 Up Weight, Average B/O = 40,000 Ibs. Found Joint #8 partially unscrewed wI 2.5" of threads exposed. Centrilizers every 4th joint starting wI #1. Recovered 40 jts 9 5/8" CSG, Cut jt Lenght 28.32' Clean Cut, 10 bow spring Centralizers, Centralizers in poor condition missing blades and 1/2 of a Centralizer. 20:00 - 21 :00 1.00 CASE P DECOMP RID CSG equipment. Clear and Clean Rig Floor. 21 :00 - 23:30 2.50 CASE P DECOMP MIU Back off BHA, consisting of Cutter, XO, Stabilizer, XO, 9-Drill Collars, XO, BHA Lenght = 289.03'. 23:30 - 00:00 0.50 CASE P DECOMP RIH with Wash Over assembly slowly to prevent pipe from running over. 12/9/2006 00:00 - 00:30 0.50 FISH P DECOMP Continue to RIH to 1,787', Obtain Parameters Up Weight = 76,000#, Down Weight=76,000#, Rotating Weight= 80,000# at 85 rpm, 5,000 ft-Ibs Torque, 7 bpm, at 240 psi. 00:30 - 01 :00 0.50 FISH P DECOMP Tag Stub at 1,787', Wash Down to 1,815',80 rpm, 5,000 to 10,000 ft-Ibs Torque, 7 bpm w/440 psi. 01 :00 - 02:00 1.00 FISH P DECOMP Pump 20 bbl Hi-Vis Sweep at 12 bpm at 700 psi. 02:00 - 02:30 0.50 FISH P DECOMP BID T/D POOH f/1 ,815', t/289'. 02:30 - 04:30 2.00 FISH P DECOMP Stand Back Drill Collars, BIO and UD 133/8" Scraper, Wash Pipe and Shoe. Recovered 1/2 Bow Spring Centralizer in Wash Pipe. 04:30 - 05:00 0.50 FISH P DECOMP Clear and Clean Rig Floor. 05:00 - 05:30 0.50 FISH P DECOMP Pump Out BOP Stack, Observed Large portion of Bow Spring Centralizer across ram body. Fished Centralizer with grapple. 05:30 - 06:30 1.00 FISH P DECOMP P/U 3-1/2" String Magnet on Joint of Drill Pipe and Fish Junk out of Lower Ram Cavities. 06:30 - 08:30 2.00 FISH P DECOMP M/U Back Off Tool w/3 Stands of Collars Below. 08:30 - 10:00 1.50 FISH P DECOMP RIH to 2112' Fill every DP every 5 stands. Obtain Initial Parameters; Up Wt = 80,000 Ibs, DW Wt = 80,000 Ibs. 10:00 - 11 :00 1.00 FISH P DECOMP Engage Back Off. Back Off 9-5/8" Casing @ 1802'. Required 20,000 ft-Ibs to BIO, put 7 rounds into it. Drop Ball and Circ Thru Sub. 11 :00 - 12:00 1.00 FISH P DECOMP Circ Btms Up at 12 bpm and 660 psi. Break Off and Blow Down Top Drive. 12:00 - 13:00 1.00 FISH P DECOMP POOH and Stand Back DP in Derrick. Stab TIW and prep for Safety Stand Down Meeting. 13:00 - 15:00 2.00 FISH P DECOMP Safety Stand Down Meeting With A-Crew. 15:00 - 16:00 1.00 FISH P DECOMP M/U Spear Assembly, BHA consists of Bull Nose,Spear Pack off, 8.25" Spear, Spear Extendsion, Stop Sub, XO. BHA Lenth = 16.12'. 16:00 - 16:30 0.50 FISH P DECOMP RIH To 1,787'. 16:30 - 17:00 0.50 FISH P DECOMP Obtain Parameters, Latch and Back Out Fish, CBU at 10 bpm w/450 psi. 17:00 - 17:30 0.50 FISH P DECOMP POOH 17:30 - 19:00 1.50 FISH P DECOMP UD CSG Stub, Lenght = 15.22'. UD Spear Assembly. 19:00 - 19:30 0.50 FISH P DECOMP Clear and Clean Rig Floor. 19:30 - 20:30 1.00 FISH P DECOMP RlU to Run 95/8",40#, L-80, TC-II Casing 20:30 - 00:00 3.50 FISH P DECOMP Run 9 5/8",40#, L-80, TC-II Casing, Using Jet Lube Seal Gaurd on all Connections, average M/U Torque 12,500 ft-Ibs. 12/10/2006 00:00 - 04:00 4.00 CASE P TIEB1 Continue to Run 9 5/8",40#, L-80,TC-11. Casing, Using Jet Lube Printed: 12/18/2006 11 :26:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/25/2006 12/1 5/2006 Spud Date: 2/15/1989 End: 12/10/2006 00:00 - 04:00 4.00 CASE P TIEB1 Seal Guard on all Connections, average MIU Torque 12,500 ft-Ibs. 1 Solid Body Straight Bladed Centralizer per Jt between Jt #1 and Jt #42 04:00 - 04:30 0.50 CASE P TIEB1 P/U 10' and 15' 95/8" Pup Jts. MIU Jt 43, MIU XOs to Top Drive, Obtain Parameters- Up Weight = 102,000#, Down Weight = 100,000#, Free Torque 3,000 ft-Ibs, at 5 rpm. 04:30 - 05:00 0.50 CASE P TIEB1 MIU Triple Connect to Casing Stub at 1,802' and Torque to 11,000 ft-Ibs work torque Down and Pull Test to 250,000 Ibs Up Weight. 05:00 - 06:30 1.50 CASE P TIEB1 Pressure Test 9 5/8" CSG to 2,000 psi for 30 minutes on Chart. 06:30 - 07:00 0.50 CEMT P TIEB1 Set Casing in slips wI 150,000 Ibs, BIO Top Drive and RID XO. Rig Up HES Cmt Head, Lines and Hoses. 07:00 - 07:30 0.50 CEMT P TIEB1 PJSM wI Dowell, Rig Crew and Vac Truck Drivers. 07:30 - 08:30 1.00 CEMT P TIEB1 P/U to 250,000 Ibs on Casing. Pump Down Casing String and Shear ES Cmtr at 2600 psi with 3.0 bbls. Circ 200 bbls of 9.8 ppg brine while waiting on Dowell to batch up cement. Temp of returns at 90 degrees. 08:30 - 09:00 0.50 CEMT P TIEB1 Press Test Cement Lines and Dowell hoses to 4500 psi. Come on Line with Cmt. Pump 115 bbls of Cmt at 5 bpm at -200 psi. 15.8 ppg Class G Cement Slurry wI Gas Block Additive. 09:00 - 10:00 1.00 CEMT P TIEB1 Drop ES Cementer Closing Plug. Displace Cmt wI 5 bbls wash up from Dowell and 129.5 bbls of 9.8ppg brine with rig pumps. Cement at surface with -130 bbls of displacement, approximately 5 bbls of cement retums. Displace Cmt wI 5 bpm for first 125 bbl, 2 bpm for 6 bbls and 1 bpm for last 3.5 bbls. Total displacement of 134.5 bbls to land plug and another 0.5 bbls to close ES Cementer. Final Closing Pressure 1800 psi. Hold Pressure for 2 minutes and then bleed off and monitor for flow. Plug Holding. Cement in Place at 09:40 am. 10:00 - 10:30 0.50 CEMT P TIEB1 Pump Cement Retarder across BOP stack and Flush Out OA Valve and Hardline. Rig Down Cement Head and Suck Out Casing Down to Wellhead. Blow Down Stack, OA, and Hardline to Tank. 10:30 - 11 :00 0.50 CEMT P TIEB1 Split Stack and M/U 9-5/8" Emergency Slips Around Casing. Slack Off on Casing and Set Slips with 185,000 Ibs. RILDS and Secure Packing Glands. M/U Wachs Cutter and Cut Casing. 11 :00 - 12:00 1.00 WHSUR P TIEB1 Pull and UD Cut Casing Jt. Nipple Down Tubing Spool. 12:00 - 13:30 1.50 WHSUR P TIEB1 N/U New 13-5/8" McEvoy Tubing Spool with Packoff. 13:30 - 15:00 1.50 WHSUR P TIEB1 Test Pack Off to 2400 psi for 30 mins. 15:00 - 16:00 1.00 WHSUR P TIEB1 N/U BOPE 16:00 - 19:30 3.50 CASE P TIEB1 Wait on Cement, Service Top Drive, Crown and Traveling Blocks, Iron Rough Neck, Draworks. 19:30 - 20:30 1.00 CASE P TIEB1 Set Test Plug, Body Test BOPs, Pull Test Plug, Set Wear Ring. 20:30 - 21 :30 1.00 CASE P TIEB1 M/U Drill Out Assembly, BHA Consists of 8.5" Bit, 3-Boot Baskets, 9.625" CSG Scraper, XO, Bumper Sub, Jar, XO, 9-6.25" Drill Collars, XO,BHA Lenght = 321.36 21 :30 - 00:00 2.50 CASE P TIEB1 Continue to WOC. Load, Tally, Drift 4.5",12.6#, 13Cr80 JFE Bear Tubing. 12/11/2006 00:00 - 00:30 0.50 CASE P TIEB1 Continue to Wait on Cement Printed: 12/18/2006 11 :26:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/25/2006 12/15/2006 Spud Date: 2/15/1989 End: 12/11/2006 00:30 - 01 :00 0.50 CASE P TIEB1 RIH w/3 stds, 6.25" Drill Collars, Drill Pipe to 1,661' Obtain Parameters, Down Weight= 77,000#, Up Weight=80,000#, 100 rpm w/3,000 ft-Ibs Torque. 01 :00 - 05:30 4.50 CEMT P TIEB1 RIH Top of Cement at 1,777', Drill Out CMT f/1 ,777 to Top of ES Cementer at 1,791' Time Drill Through ES Cementer Baffle Plate at 1,794' at 80 RPM 3,000 to 4,000 ft-Ibs Torque 12 bpm w1750 psi, 10,000 to 15,000# WOB. Reduce WOB to 7,000# to 10,000#. Pump 20 bbl HI-Vis Sweep at 11 BPM with 750 psi, Continue to Drill Through Baffle Plate. Rotate and Reciprocate Through Cementer and Baffle Plate. Circulate Hole Clean at 14 BPM and 1010 psi. 05:30 - 06:00 0.50 CLEAN P CLEAN RIH to Top of Sand. Top of Sand at 2740' work down to 2748'. Increased Torque Indicates there is junk on sand. 06:00 . 07:00 1.00 CLEAN P CLEAN Displace Hole to 8.45 ppg Seawater. 07:00 . 07:30 0.50 CLEAN P CLEAN POOH and rack back stands to 2330' 07:30 - 08:30 1.00 CLEAN P CLEAN Pressure Test Casing to 3500 psi for 30 mins. Good Test. 08:30 - 09:30 1.00 CLEAN P CLEAN POOH and Rack Back Drill Pipe. 09:30 - 10:30 1.00 CLEAN P CLEAN Rack back Drill Collars and BIO BHA. 10:30 - 11 :00 0.50 CLEAN P CLEAN Clean Out Junk Baskets and P/U RCJB. 11 :00 - 12:30 1 .50 CLEAN P CLEAN RIH with DC's and DP to 2748'. 12:30 - 13:30 1.00 CLEAN P CLEAN Obtain initial parameters and clean out well from 2748' to 2763'. Circulate around 40 bbl high visc sweep and chase out of the hole. 13:30 - 14:30 1.00 CLEAN P CLEAN POOH with DP and DC's 14:30 - 15:30 1.00 CLEAN P CLEAN B/O BHA and Clean Out RCJB and Boot Baskets. Found a good amount of metal in RCJB plus large rubber plug from ES Cementer. 15:30 - 17:00 1.50 CLEAN P CLEAN RIH wI RCJB again to 2763' 17:00 - 18:00 1.00 CLEAN P CLEAN Obtain Initial Parameters and Wash from 2763' to 2770'. Circ around 40 bbl high visc sweep. 18:00 - 18:30 0.50 CLEAN P CLEAN Blow Down Surface Lines, POOH. 18:30 - 19:30 1.00 CLEAN P CLEAN Handle BHA Service Reverse Circulating Junk Basket, Lay Down Reverse Circulating Junk Basket. 19:30 - 20:30 1.00 CLEAN P CLEAN M/U RBP Retrieval Tool, RIH, Obtain Parameters. 20:30 - 21 :30 1.00 CLEAN P CLEAN Tag Sand at 2,777' Wash to 2,800' At 10 bpm w/440 psi Pump 40 bbl Hi- Vis Sweep at 14 bpm w/1,000 psi. Latch and Pull 15,000 Ibs Slack off 15,000 Ibs 1/4 to Left and Release RBP. 21 :30 - 22:00 0.50 CLEAN P CLEAN CBU at 10 bpm and 600 psi. 22:00 - 23:00 1.00 CLEAN P CLEAN POOH f/2,800'. 23:00 - 23:30 0.50 CLEAN P CLEAN UD RBP Assembly. 23:30 - 00:00 0.50 CLEAN P CLEAN P/U Reverse Circulating Junk Basket. 12/12/2006 00:00 - 00:30 0.50 DHEQP P DECOMP Continue to MIU Reverse Circulating Junk Basket, RIH 3 Stds 6.25" Drill Collars. 00:30 - 01 :30 1.00 DHEQP P DECOMP RIH w/Drill Pipe to 3,104', Drop Opening Ball, Rotate down to 3,200' at 40 rpm, 7 bpm, w/2,900 psi. 3,000 ft-Ibs Torque. Begin to Pump Down under RBP Setting Depth of 2,800' to Circulate up Fish Lost From String Shot Run. 01 :30 - 02:00 0.50 DHEQP P DECOMP RIH to 3,700' 02:00 - 02:30 0.50 DHEQP P DECOMP Circulate 20 bbl Hi-Vis Sweep at 7 BPM w/2,500 psi, 40 RPM, 3,000 ft-Ibs Torque. 02:30 - 07:00 4.50 CLEAN P DECOMP RIH to 12,333' Rotating and Circulating every 5 Stds at 40 RPM, 7 BPM w/2,500 psi. 07:00 - 08:30 1.50 CLEAN P DECOMP Obtain Parameters, 250,000 Up Weight, 125,000 Down Printed: 12/18/2006 11 :26:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11/25/2006 12/15/2006 Spud Date: 2/15/1989 End: 12/12/2006 07:00 - 08:30 1.50 CLEAN P DECOMP Weight, 20-40 rpm, 12,000 ft-Ibs Torque, 7 bpm w/3,000 psi. Worked Reverse Circulating Junk Basket Above RBP At 12,333'. In an attempt to Recover Fish From String Shot Run. 08:30 - 09:00 0.50 CLEAN P DECOMP Attempt to open Circulation Sub. Dropped Opening Ball and Pumped Down, Appeared Ball Would Not Seat, Could Not Shear Sub. 09:00 - 09:30 0.50 CLEAN P DECOMP POOH to 11,920' 09:30 - 11 :00 1.50 CLEAN P DECOMP Ball On Seat Opened Circulation Sub Pump 40 bbl Hi-Vis Sweep at 12 bpm w/3100 psi. 11 :00 - 15:00 4.00 CLEAN P DECOMP BID T/D Continue to POOH to BHA. 15:00 - 16:30 1.50 CLEAN P DECOMP Lay Down Reverse Circulating Junk Basket Assembly, Recovered Two Pieces of Sled Nose, Lost in Hole From String Shot Wireline Run. 16:30 - 17:00 0.50 CLEAN P DECOMP Make Up RBP Retrieving Tool and RIH w/Drill Collars. 17:00 - 20:30 3.50 CLEAN P DECOMP RIH to 12,271'. 20:30 - 22:30 2.00 CLEAN P DECOMP Obtain Parameters, Latch and unset RBP at 12,333'. Hole Went on Vacuum, Attempt to Fill the Hole Filled on Annulus side w/150 bbls of Sea Water. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH Laying Down Drill Pipe, Filling Hole at 60 bph and Double Displacing. 12/13/2006 00:00 - 08:00 8.00 CLEAN P DECOMP POOH Laying Down Drill Pipe, Filling Hole at 60 bph and Double Displacing. 08:00 - 09:00 1.00 CLEAN P DECOMP UD 9 - 6.25" Drill Collars, RBP and RBP Running Tool. 09:00 - 09:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 09:30 - 10:00 0.50 RUNCO RUNCMP Pull Wear Ring. 10:00 - 14:00 4.00 RUNCO RUNCMP RlU to Run 4.5",12.6#, 13Cr80, Completion. 14:00 - 00:00 10.00 RUNCO RUNCMP P/U and Run 4.5",12.6#, 13Cr80, Vam Top Mule Shoe, 1 - Jt 4.5",12.6#, 13Cr80, Vam Top Tubing.1- X Nipple w/RHC-M Plug, 4.5"x 9.625" Baker S-3 Production Packer, 1-X Nipple, 45 jts of 4.5",12.6#, 13Cr80, Vam Top Tubing. Using Jet Lube Seal Guard Thread Compound on All Connections, Making up Tubing Using Compensator and Torque Turn, Average M/U on Vam Top 4,400 ft-Ibs. P/U GLM #1and XO to 4.5",12.6#, 13Cr80, JFE Bear Tubing Using Jet Lube Seal Guard Thread Compound and Compensator, Touque Turning All Connections, Average M/U 4,500 psi. Ran Total of 136 jts. 12/14/2006 00:00 - 07:30 7.50 RUNCO RUNCMP Continue to Run 4.5",12.6#, 13Cr80, JFE Bear Completion, Average M/U 4,500 ft-Ibs of Torque, Using Jet Lube Seal Guard Pipe Dope with Compensator and Torque Turning All Connections, f/5,707' t/12,352' Obtain Parameters Up Weight =187,000 Ibs, Down Weight = 102,000 Ibs. 07:30 - 08:00 0.50 RUNCO RUNCMP Continue to RIH Tagged top of 5.5" Tubing Stub with Mule Shoe at 12,392', P/U Rotate Pipe 2 Revolutions And Slack Off into 5.5" Stub. Continue to Slack Off to No-Go at 12,432' 08:00 - 09:00 1.00 RUNCO RUNCMP UD joints 305,304 and 303 P/U 3' XO and 10' Pup P/U 1jt Vam Top Tubing, Tubing Hanger and Landing Jt. 09:00 - 09:30 0.50 RUNCO RUNCMP RIH Tagged 5.5" Tubing Stub at 12,392' w/Mule Shoe, P/U and Rotate Pipe Twice, Slacked Off and Landed Tubing Hanger, Space Out 11' fINo-Go at 12,432'. 09:30 - 10:00 0.50 RUNCO RUNCMP RILDs 10:00 - 15:00 5.00 RUNCO RUNCMP Circulate in 780 bbls of 140 deg Sea Water with Corrosion Inhibitor at 3 bpm w/20 psi. 15:00 - 16:00 1.00 RUNCO RUNCMP RlU and Attempt to Set Baker S-3 Production Packer, Pump Printed: 12/18/2006 11:26:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 11 /25/2006 12/15/2006 Spud Date: 2/15/1989 End: 187 bbls at 5 to 8 bpm w/450 psi, Packer Setting Ball Would Not Seat in RHC-M. 16:00 - 17:00 1.00 RUNCMP Pump 60 bph Down Tubing and Discussing Options 17:00 - 18:30 1.50 RUNCMP MIU Landing Jt, BOLDs, Pull Hanger to Rig Floor and Work and Rotate Pipe 180 deg in as attempt to get Packer Setting Ball Moving Down Hole, Continue to Work Pipe. Change Out Tubing Hanger Rubber Element. Land Tubing RILDs. 18:30 - 19:00 0.50 RUNCMP Pump to Seat Packer Setting Ball at 3 bpm for 19 bbls, Ball and Rod Seated. 19:00 - 21 :00 2.00 RUNCMP Wait on Sea Water to Replace Packer Fluid Lost to Formation. 21 :00 - 00:00 3.00 RUNCMP Mix Corrosion Inhibitor onto Vac Trucks and pump Corrosion Inhibited Sea Water at 3 bpm w/20 psi. 12/15/2006 00:00 - 01 :30 1.50 RUNCMP Continue to Pump Corrosion Inhibited Sea Water Down IA at 3 bpm wI no Returns. 01 :30 - 03:00 1.50 RUNCMP Pressure up on Tubing Set Packer at 2,500 psi Continue to Pressure up to 3,500 psi and Hold for 30 Charted Minutes, Top Off Annulus with Corrosion Inhibited Sea Water approx 25 bbls wlCharge Pump While Holding Test on Tubing Good Test. Bled Down Tubing to 1,500 psi and Pressured up to 3,500 psi on Annulus for 30 Charted Minutes good Test. Bled Down Tubing Pressure and Sheared DCR Valve. Circulated in Both Directions to Confirm flow Path. 03:00 - 03:30 0.50 RUNCMP Set TWC and Pressure Tested to 1,000 psi flBelow and 3,500 psi from Above, BID RID Circulating Lines 03:30 - 05:30 2.00 RUNCMP Drain and Nipple Down BOPs, N/U Adapter Flange. 05:30 - 06:00 0.50 RUNCMP Were not Able to Obtain Required M/U on Adapter Flange, Discuss Options 06:00 - 08:30 2.50 RUNCMP Remove Adapter Flange Pull Studs, Had New Ones Cut at Baker Machine Shop. 08:30 - 10:00 1.50 RUNCMP New Studs Would Not Make Up to Adapter Flange, ReTap Bolt Holes in Adapter Flange, M/U Studs Install and Nipple Up Adapter Flange. 10:00 - 11 :00 RUNCMP Install and Nipple Up Production Tree. 11 :00 - 12:00 RUNCMP RlU and Test Neck Seal and Void Space on Adapter Flange. 12:00 - 13:00 RUNCMP Attempt to Test Tree, RlU Tee and Sensor tITop of Tree wlNeddle Valve on Top of Sensor, TWC Leaking RID Test Equipment. 13:00 - 14:00 1.00 RUNCMP RlU DSM Lubricator Pull TWC, Dry Rod in New TWC. RID DSM. 14:00 - 15:30 1.50 RUNCMP Fill Tree w/Diesel RlU and Test Tree to 5,000 psi for 5 minutes. RID Test Equipment. 15:30 - 16:00 0.50 RUNCMP RlU DSM Lubricator and Pull TWC, RID DSM. 16:00 - 18:00 2.00 RUNCMP RlU Little Reds Test Lines to 3,500 psi, Pump145 bbls of 70 deg Diesel Down Annulus at 2 bpm 670 psi. 18:00 - 19:00 1.00 RUNCMP U-Tube Well. 19:00 - 19:30 RUNCMP Set BPV Tested to 1,000 psi f/15 minutes. 19:30 - 20:30 RUNCMP Blow Down, RID Little Reds. BID RID Surface Lines. 20:30 - 21 :30 RUNCMP Nipple Down Double Annulus Valve and Secure Well. Printed: 12/18/2006 11 :26:42 AM , . TREE= 4-1/16X5MGEN4 WB..LHEAO = MCEVOY ACTUA TOR = AXB..SON KB. B..EV = 74' BF. B..EV = KOP = 900' Max Angle = 57 @ 7900' Datum MO = 13019' Datum TVO = 8800' SS 19-5/8" CSG, 40#, L-80. TC-II H 2200' 113-3/8" CSG, 68#/72#, K-55/L-80, 10 = 12.415" I 4434' Minimum ID = 3.725" @ 12369' 4-1/2" OTIS XN NIPPLE I TOP OF 5-1/2" TBG STUB (02/26/05) H 14-1/2" TBG, 12.6#, 13CRBO, .0152 bpf. 10 = 3.958" I 15-112" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" H 1 TOP OF 4-1/2" TBG I TOP OF 7" LNR H 14-1/2" TBG, 12.6#. L-80, .0152 bpf, 10 = 3.958" I 1 9-5/8" CSG, 47#, L-80. 10 = 8.681" I ~ 12-32 FROM DRLG - DRAFT 12480' 12540' ÆRFORA TION SUMMA RY REF LOG: BHCS ON 03/12/89 ANGLEATTOPÆRF: 43 @ 12792' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 4 12792 - 12822 0 07/10/94 3-3/8" 4 12930 - 12948 0 02/13/91 3-3/8" 4 12960 - 12980 0 12/26/92 3-3/8" 4 12992 - 13033 0 06/05/89 3-3/8" 4 13037 - 13072 0 06/05/89 3-3/8" 413076-13111 0 06/05/89 3-3/8" 4 13116 - 13126 0 06/05/89 3-3/8" 4 13130 - 13140 0 06/05/89 PBTD I 17" LNR, 29#. L-80, .0371 bpf, 10 = 6.184" H æ::::J DATE 03/22/89 03/05/05 03/17105 08/28/05 09/24/05 07/21/06 REV BY COMMENTS ORIGINAL COM PLETION KCF/TLH RWO OTRlPJC GLV C/O EZUTLH WM/ER SFTY NOTE OB..ETED MOR/TLH XXN TIP SET (08/29/05) OFRlPJC JET CUT TBG 13454' 13499' 13500' DATE 12/15/06 12/19/06 01/03/07 01/04/07 2031' 14-112" HES X NIP, 10 = 3.813" I GAS LIFT MANORB..S OEV TYÆ VLV LATCH 48 MMG DOME RK 51 MMG OMY RK 53 MMG SO RK 51 MMG OMY RK 52 MMG OMY RK ST MO 5 3630 4 4840 3 7513 2 9552 1 10367 12262' 1229~ 12327' 12421' 12423' 12425' 12442' S NOTES: OA DOWN-SQZ'D. *** 4-112" CHROME TBG *** TVD 3004 3819 5420 6613 7130 PORT DATE 16 01/03/07 o 12/13/06 20 12/13/06 o 12/13/06 o 12/13/06 14-112" HES X NIP, 10 = 3.813" 1 19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, 10 = 3.813" -14-1/2" WLEG, ID = 3.958" I 9-5/8" X 5-1/2" BAKER FB-1 PKR 5-1/2" BAKER SEAL BORE EXT 5-1/2" X 4-1/2" XO (7-5/8" X 4-1/2" XO BB..OW MILLOUT EXT.) -14-1/2" OTIS XN NIP, 10 = 3.725" I 12540' -14-1/2" WLEG I 12513' H B..MO TT LOGGED 12/03/89 13046' 13124' REV BY COMMENTS JW/CH RWO Doyon 16 ?/PAG CORRECTIONS RCT/TLH GL V C/O KSB/TLH FISH TAGGED OEPTHlA..UG OUT 5-1/2" FASDRILL A..UG. MILLED OUT & PUSHED TO THIS DEPTH ON 02/26/05 TD TAGGED 01/04/07 10' OF 1.25" STEIv1 W/1.188" FN & BOX END BROKEN OFF (LOST 04/23/96) PRUDHOE BAY UNIT WB..L: 12-32 ÆRMIT No: 1890110 API No: 50-029-21910-00 SEC 17, T10N, R15E, 1909.03' FB.. & 648.29' FNL BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-32 Sundry Number: 306-352 (}Jo\\ \~-\ Dear Mr. Reem: 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 thisiliay of October, 2006 Encl. oiS I 1// rdJ, ,1.r7h lJp WúA- 11D11...c-{1..Oo c... 10 271ft? n~. STATE~F/A!:!ll.A~¡' n ~ I~Wc.bRECE/VED ,," ~~:prÞV ALASKA OIL AND GAS CONSERVATION COM.ON f' ¡ . '1\ V APPLICATION FOR SUNDRY APPROVAL . ! 2 4 2006 , 20 AAC 25 280 Alask ion ~a uu è~ Gii~ t'rH". f\_ 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension Am:;!wrage ,,~ o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 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 189-011 / 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21910-00-00 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: , property line where ownership or landownership changes: PBU 12-32 / Spacing Exception Required? DYes 181 No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028331 74' Prudhoe Bay Field / Prudhoe Bay Pool 112; .... .. ....> ....,... ···i·i·./ '. ..\i\ i// ....... ..' VVE:L . l.\¡, ''fUI IVI" Total Depth MD (ft): Total Depth TVD (ft):IEffective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13500 9223 13454 9191 12527' 12548 Casino Lenoth Size MD / TVD Burst Collacse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4434' 13-3/8" 4434' 3554' 3450 1950 Intermediate Production 12793' 9-5/8" 12793' 8709' 6870 4760 Liner 1019' 7" 12480' - 13499' 8487' - 9222' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 12792' - 13140' I 8708' - 8963' 4-1/2", 12.6# x 5-1/2" 13Cr85/ L-80 12540' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'FB-1' packer; 9-5/8" x 4-1/2" Baker ¡packers and SSSV MD (ft): 12423'; 12292' / '8-3' packer; 4-1/2" 'X' Nipple 2080' 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program /~ 15. Estimated Date for Novembt6Jo06 16. Well Status after proposed work: CommencinQ Operations: IZI Oil o Gas D Plugged D Abandoned 17. Verbal Approval: DateV, 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 Howard West, 564-5471 Printed Naml'Pavid Reem Title Drilling Engineer /:)..{/ jI/J A... _ Prepared By Name/Number: Signature Phone 564-5743 Date 1'{)12+/~ Sondra Stewman, 564-4750 Commission Use Onlv I Sundry Number:.::riJl "!" "^5.<"J 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. s t- Bore +0 3S"oo ¡iÎ , . \ Subsequent Fann Roou;,.d: 1(') -((j~ APPROVED BY If) '~f-OÞ Approved Bv: ...,.- / I COMMISSIONER THE COMMISSION Date Form 10-403 vised 06/2006 V ......- - Submit In Duplicate OR\G\NAL RBDMS 8Ft 0 CT 3 0 2006 . . G 12-32 Rig Workover Scope of Work: Retrieve existing 4.5", 12.6#completion, mill and retrieve baker S-3 packer, locate top of cement in 9-5/8" x 13-3/8" annulus, cut and pull the 9-5/8" casing above the TOC, ,,/ tie-back premium threaded 9-5/8" to surface and fully cement same. Re-complete well as a 'stacker packer' completion with 4.5", 12.6#, 13Cr-80 VamTop tubing. Provide AOGCC field :::tZ;~: notices as required to witness BOP tests and MITrA post packer setting. Well TY~OdUCer Estimated Start Date: Nov. 26, 2006 Pre-rig prep work: Pre-Rig: 0 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is secured at this time with a TIP. PPPOT-T & IC. S 2 Drift thru 4- Y2" tubing for Power-jet cutter. E 3 Power-jet cut 4-Yz" 13Cr-SO tubing 1 - 2' above the S-3 packer. Cut depth=12291'md based on 2-2S-2005 tally. F 4 Circulate well with seawater and diesel thru the cut. CMIT TxlA to 3500 psi. M ITOA to 2000 psi. 0 5 Set a BPV in the tubing hanger. 0 6 Remove the wellhouse & flow line. Level the pad as needed for the rig. ./ Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to ~~~si. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. ~~ 2. Pull and LD 4-1/2" tubing string to the cut. 3. Mill and retrieve the Baker S-3 packer. 4. Run USIT and locate top of cement in 9 5/S" x 13 3/S" annulus. 5. Mechanically cut the 9 5/S" above the TOC. Circulate out annulus fluids, LD 9 5/S" down to the cut. 6. Run 9-5/S" screw-in sub on 9-5/S", 40#, L-SO I casing. Screw back in to stub. Pull test to 250K. 7. Land casing on emergency slips in existin tubi spool. 8. Fully cement the 9-5/S" to surface. PT casin 03500 psi for 30-minutes (charted). 9. Run 4-1/2" 13Cr80 completion with Baker S-3 packer. Set and test packer to 3500 psi (tubing and inner annulus) for 30 mins. each (charted). 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. / / / /' TREE = 4-1/16 X 5M GEN 4 WELLHEAD = MCEVOY ACTUA TOR = AXELSON KB. ELEV = 74' BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 900' 57 @ 7900' 13019' 8800' SS . , 13-3/8" CSG, 68#/72#, K-55/L-80, ID = 12.415" I 4434' Minimum ID = 3.725" @ 12369' 4-1/2" OTIS XN NIPPLE I JET CUT TUBING (07/21/06) 1 TOP OF 5-1/2" TBG STUB (02/26/05) H 14-1/2" TBG, 12.6#, 13CR80, .0152 bpf, ID = 3.958" I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H TOPOF 4-1/2" TBG I TOPOF 7" LNR H 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 12290' 12480' 12540' 12-32 ÆRFORA TION SUMIIi1ARY REF LOG: BHCS ON 03/12/89 ANGLEAT TOP ÆRF: 43 @ 12792' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 4 12792 - 12822 C 07/10/94 3-3/8" 4 12930 - 12948 C 02/13/91 3-3/8" 4 12960 - 12980 C 12/26/92 3-3/8" 4 12992 - 13033 C 06/05/89 3-3/8" 4 13037 - 13072 C 06/05/89 3-3/8" 4 13076 - 13111 C 06/05/89 3-3/8" 4 13116 -13126 C 06/05/89 3-3/8" 4 13130 - 13140 C 06/05/89 IPBTD I 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H ~ DATE 03/22/89 03/05/05 03/17/05 08/28/05 09/24/05 07/21/06 REV BY COMMENTS ORIGINAL COM PLETION KCFITLH RWO DTRlPJC GL V C/O EZLITLH WAIVER SFTY NOTE DELETED MORlTLH XXN TIP SET (08/29/05) DFRlPJC JET CUT TBG 13454' 13499' 13500' DATE REV BY COMMENTS ~NOTES: OA DOWN-SOZ'D. 12" CHROME TBG *** 2080' H4-1/2"HESXNIP,ID=3.813" , GAS LIFT IIi1ANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 3609 2990 48 MMG DMY RK 0 02/28/05 4 4800 3793 51 MMG DOME RK 16 03/17/05 3 7469 5393 53 MMG SO RK 20 03/17/05 2 9512 6588 51 MMG DMY RK 0 02/28/05 1 10296 7086 51 MMG DMY RKP 0 02/28/05 12272' 12292' 12317' 12369' 12381' 12423' 12425' 12442' -12548 13124' 4-1/2" HES X NIP, ID = 3.813" H9-5/8" X 4-1/2" BKR S-3 A<R, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 14-1/2" HES XN NIP, ID = 3.725" 4-1/2" WLEG, 10 = 3.958" 9-5/8" X 5-1/2" BAKER FB-1 A<R 5-112" BAKER SEAL BORE EXT 5-112" X 4-1/2" XO (7-5/8" X 4-1/2" XO BELOW MILLOUT EXT.) H4-1/2" OTIS XN NIP, ID = 3.725" I -i 4-112" XXN TIP (08/29/05) I -14-1/2" WLEG I H ELMD IT LOGGED 12/03/89 I 5-112" FASDRILL PLUG, MILLED OUT & PUSHED TO THIS DEPTH ON 02/26/05 10' OF 1.25" STEM W/1.188" FN & BOX END BROKEN OFF (LOST 04/23/96) PRUDHOE BA Y UNIT WELL: "'12-32 ÆRMIT No: "1890110 API No: 50-029-21910-00 SEC 17, T10N, R15E, 1909.03' FEL & 648.29' FNL BP Exploration (Alas ka) TREE = 4-1/16 X 5M GEN 4 WB...LI'i~D = MCEVOY ACTUA TOR = AXB...SON KB. B...EV = 74' BF. B...EV = KOP = 900' Max Angle = 57 @ 7900' Datum MD = 13019' Datum TVD = 8800' SS 19-518" CSG, 40#, L-80, TC-II H 113-3/8" CSG, 68#/72#, K-55/L-80, ID= 12.415" I Minimum ID = 3.725" @ 12369' 4-1/2" OTIS XN NIPPLE I TOP OF 5-1/2" TBG STUB (02/26/05) H 14-1/2" TBG, 12.6#, 13CR80, .0152 bpf, ID = 3.958" I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I TOP OF 4-1/2" TBG I . 2200' I" 12 -32 Proposed Corrpletion I TOP OF 7" LNR H 12480' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 12540' 9-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/12/89 ANGLE AT TOP ÆRF: 43 @ 12792' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12792 - 12822 C 07/10/94 3-3/8" 4 12930 - 12948 C 02/13/91 3-3/8" 4 12960 - 12980 C 12/26/92 3-3/8" 4 12992 - 13033 C 06/05/89 3-3/8" 4 13037 - 13072 C 06/05/89 3-3/8" 4 13076 - 13111 C 06/05/89 3-3/8" 4 13116 -13126 C 06/05189 3-3/8" 4 13130 - 13140 C 06/05/89 PSTD I IT' LNR, 29#, L-80, .0371 bpf, ID = 6.184" H ~ DATE 03/22/89 03/05/05 03/17/05 08/28/05 09/24/05 07/21/06 REV BY COMMENTS ORIGINAL COMPLETION KCFITLH RWO DTR/PJC GL V C/O EZLITLH WAIVERSFTY NOTEDB...ETED MOR/TLH XXN TIP SET (08/29/05) DFRlPJC JET CUT TBG 13454' 13499' 13500' DATE COMMENTS REV BY / NOTES: OA DOWN-SQZ'D. 12" CHROMETBG*** 2000' H4-1/2"HESXNIP,ID=3.813" I 5 3624 1 1/2" MM OCR 4 4810 1 1/2" MM DGLV 3 7480 1 1/2" MMG DGLV 2 9531 1 1/2" MMG DGLV 1 #### 1 1/2" MMG DGL V 12423' 12425' 12442' -12548 13124' 4-1/2" HES X NIP, ID = 3.813" H 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 14-1/2" HES XN NIP, ID = 3.725" .,4-1/2" WLEG, ID = 3.958" I 9-5/8" X 5-1/2" BAKER FB-1 PKR 5-1/2" BAKER SEAL BORE EXT 5-1/2" X 4-1/2" XO (7-5/8" X 4-1/2" XO BB...OW MILLOUT EXT.) H4-1/2" OTIS XN NIP, ID = 3.725" I -14-1/2" XXN TIP (08/29/05) I -14-1/2" WLEG I H B...MD TT LOGGED 12/03/89 I 5-1/2" FASDRILL PLUG, MILLED OUT & PUSHED TO THIS DEPfH ON 02/26/05 10' OF 1.25" STEM W/1.188" FN & BOX END BROKEN OFF (LOST 04/23/96) PRUDHOE BA Y UNIT WB...L: "12-32 PERMIT No: "1890110 API No: 50-029-21910-00 SEC 17, T10N, R15E, 1909.03' FB... & 648.29' FNL BP Exploration (Alaska) , STATE OF ALASKA ALASKJ )IL AND GAS CONSERVATION Cc.. 11SSION ~!e!'VED REPORT OF SUNDRY WELL OPERATION!iJAR 'I 2005 Alaskd on & Gal Con.. liommissÏJn rAJåøt,age o Time Extension 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADl028331 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production liner length 12793' 1019' Perforation Depth MD (ft): Perforation Depth TVD (ft): 1m Repair Well 0 Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 74' 13500 9223 13454 9191 110' 4434' 4. Current Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 189-011 6. API Number: 50-029-21910-00-00 99519-6612 9. Well Name and Number: PBU 12-32 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) 12548 feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 13-3/8" 4434' 3554' 3450 1950 9-5/8" 12793' 8709' 6870 4760 7" 12480' - 13499' 8487' - 9222' 8160 7020 SCl-\NNEf» t\PH 1 4: 20D~j 12792' - 13140' 8708' - 8963' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4-1/2", 12.6# x 5-1/2" 13Cr85/ l-80 12540' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" X 5-1/2" Baker 'FB-1' packer; 9-5/8" x 4-1/2" Baker 'S-3' packer; 4-1/2" 'X' Nipple 12423'; 12292' 2080' Treatment description including volumes used and final pressure: RBDMS 8Ft. APR 0 1 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure 10,373 6,755 995 5,293 15. Well Class after proposed work: o Exploratory 1m Development 0 Service 16. Well Status after proposed work: 1m Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 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 Paul Chan, 564-5254 NIA Oil-Bbl Prior to well operation: 590 Subsequent to operation: 260 14. Attachments: 0 Copies of Logs and Surveys run 1m Daily Report of Well Operations o Well Schematic Diagram 13. Printed Name Terrie Hubble Signature 1'iNù t (iu ~ Form 10-404 Revised 04/2004 Tubino Pressure 1,500 241 Title Technical Assistant U RYG \ N51\L8 Date 03/3D/OS Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only ) ') Well: Field: API: Permit: 12-32 Rig W orkover Prudhoe Bay Unit 50-029-21910-00-00 189-011 Accept: Spud: Release: Rig: 02/16/05 N/A 03/02/05 Doyon 16 PRE-RIG WORK 08/24/04 PULLED JUNK CATCHER FROM 12,467 SLM. PULLED PRONG FROM 12,477 SLM. 08/25/04 MADE SEVERAL BAILER RUNS TO PLUG BODY AT 12,477 SLM. (RETRIEVED BRITTLE ASPHALTINE MATERIAL) 08/26/04 RAN 2.25" BAILER TO 12483' SLM. BAILER CAME BACK EMPTY. LATCHED PLUG BODY AT 12483' SLM WITH 4 1/2" GR.SHEARED. RAN 4 1/2" GS TO 12483' SLM. LATCHED AND PULLED 41/2" PXN PLUG BODY. 08/27/04 SET HALCO 4-1/2" (3.66" OD) FASDRILL PLUG AT 12466'. DEPTH CORRELATED TO TUBING TALLY. TAGGED PLUG AFTER SETTING AT 12466'. 02102105 TAGGED FAS DRILL AT 12,439' SLM, W/ 3.70" CENT, 3.50" LIB. 02106/05 RIH WITH 5.5" HES FASDRILL BRIDGE PLUG. OD OF PLUG 4.37". SAT DOWN AT 6669' MULTIPLE TIMES. PULLED 200 LBS OVERPULL TO GET OFF. POOH. 02107/05 SET BAKER 3-3/8 IBP AT BAKER LOCATER SEAL ASSEMBLY AT - 12431' (TUBING TALLY). JOB COMPLETE. ) ') BP EXPL()RATION Operéltiøn$SlirnrniJryFtep.ort. Legal Well Name: 12-32 Common Well Name: 12-32 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Task Code NPT 2/14/2005 23:59 - 00:00 0.02 MOB P 2/15/2005 00:00 - 03:00 3.00 RIGD P 03:00 - 06:00 3.00 RIGD P 06:00 - 07:00 1.00 RIGD P 07:00 - 09:00 2.00 RIGD P 09:00 - 15:00 6.00 MOB P 15:00 - 16:30 1.50 RIGD P 16:30 - 18:30 2.00 RIGU P 18:30 - 20:30 2.00 RIGU P 20:30 - 00:00 3.50 RIGU P 2/16/2005 00:00 - 05:00 5.00 RIGU P 05:00 - 11 :00 6.00 KILL P Start: 2/15/2005 Rig Release: 3/2/2005 Rig Number: Spud Date: 2/15/1989 End: Phase Desëription of Operations PRE Prep rig to move off of DS7-09 PRE Back rig off DS 7-09. PRE Prepare top drive, service loop and torque tube for laying down derrick. PRE Lay derrick over and chain down for move to DS 12. PRE PJSM and install booster wheels. PRE Move rig from DS 7 to DS 12. PRE PJSM and remove booster wheels from sub. PRE Lay herculite & mats. Spot equipment. PRE PJSM. Raise derrick. RU floor. PRE Spot rig. Wellhead is too high to get BOP on wellhead. Move rig off. Double mat to raise rig up an additional 6 inches. Re-position rig. PRE Accept rig on DS 12-32 at 00:01 hrs on 2/16/05. Take on seawater. Finish berming around rig. Put slop tank in place. RU to circulate thru choke manifold. RD bridle lines. DECOMP P/U Lubricator, pull BPV. Tubing Pres 30 psi; Casing Pres 50 psi. Bleed down both sides and pressures reach 0 psi in a few seconds. Well is dead. Reverse circulate diesel out of tubing 3 BPM @ 30 - 280 psi. Align valves for long way, and resume circulation @ 3 BPM, 80 psi for 760 Bbls. Returns are clean 8.5 (+/-) ppg seawater. S/ pump and monitor well pressures; well dead. Load and Tally DP in Pipe Shed. PJSM. Bleed down lines and Tree. Install BPV per instructions from Cameron Wellhead Technician. N/D Tree and Adaptor Flange. N/U BOPE. Very tight on vertical clearance from btm flange on stack to top of tubing spool. Calibrate gas alarms while NU BOPE. Install landing jt. Test annular and upper pipe rams to 250/3500 psi - verified by Co Rep. AOGCC rep, Jeff Jones, waived witnessing this test. Blow down lines after testing rams & annular. Pull landing jt. RU DSM & pull BPV. RD DSM. Re-run landing jt. Unseat hanger with 160 klbs. Continue pulling on landing jt up to 225 klbs - no pipe movement & max pull for elevators. Chg to 175 ton elevators. Continue working pipe up to 315 klbs total load - 278 klbs max for tubing plus -37 klbs for top drive. No success. Pipe appears to be not fully separated. Previous circulation to remove freeze protect from well indicated unrestricted circulation. DPRB DECOMP Order out E line unit to chemical cut 5.5" tubing. Pull up to 315 klbs on tubing and let sit. Work pipe down & up every 15 minutes while waiting on E line unit. DPRB DECOMP PJSM. Rig Up Schlumberger equipment for three runs: 1 )-Calibration and Depth Selection for Chemical Cut: 2)-String Shot on Depth; and 3)-Chemical cut immediately above the earlier reported part which now appears to be a collapsed tubing joint. DPRB DECOMP Failure of Schlumberger tool to read-out to surface. POOH and re-rig. 11 :00 - 14:00 3.00 WHSUR P DECOMP 14:00 - 22:00 8.00 BOPSUR P DECOMP 22:00 - 00:00 2.00 BOPSUR P DECOMP 2/17/2005 00:00 - 00:30 0.50 BOPSUP P DECOMP 00:30 - 01 :30 1.00 WHSUR P DECOMP 01 :30 - 01 :45 0.25 PULL P DECOMP 01 :45 - 03:30 1.75 PULL P DECOMP 03:30 - 07:00 3.50 PULL N 07:00 - 10:00 3.00 PULL N 10:00 - 11 :00 1.00 PULL N Printed: 3/7/2005 9:44:40 AM ) ) Legal Well Name: 12-32 Common Well Name: 12-32 Spud Date: 2/15/1989 Event Name: WORKOVER Start: 2/15/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/2/2005 Rig Name: DOYON 16 Rig Number: Date From.; To Hours Task· GOdeNPT . Phase 2/17/2005 11 :00 - 13:30 2.50 PULL N DPRB DECOMP RIH wi GRICCL and 4.3" Gage Ring. Log on depth, find obstruction @ 11,715' ELM. Repeat tag to verify and have to pull to 1,900 Ibs to get out of obstruction. Decide to make chem Cut @ 11,690' 13:30 - 15:30 2.00 PULL N DPRB DECOMP POOH to P/U String shot. 15:30 - 16:30 1.00 PULL N DPRB DECOMP PJSM. M/U two-strand string shot. 16:30 - 19:00 2.50 PULL N DPRB DECOMP RIH wi String Shot to 11,690'. Log on depth and fire string shot. 19:00 - 20:30 1.50 PULL N DPRB DECOMP POH to 200' & park Eline. 20:30 - 20:45 0.25 PULL N DPRB DECOMP Hold PJSM for retrieving stringshot and then making up chemical cutter. BP, Doyon, SWS participate. Block entries to rig floor. 20:45 - 21 :30 0.75 PULL N DPRB DECOMP Pull to surface & lay down string shot - fired but some of the plastic coating left on SS strip. Chk wi SWS base & told OK to proceed. SWS suit up and make up chemical cutter. MU packoff. 21 :30 - 23:00 1.50 PULL N DPRB DECOMP RIH and log on depth to sever 51/2" tubing at 11690' ELMD. Good indication of detonation at surface. 23:00 - 00:00 1.00 PULL N DPRB DECOMP POH with cutter to 200'. 2/18/2005 00:00 - 00:15 0.25 PULL N DPRB DECOMP PJSM for RD SWS packoff & handling chemical cutter. 00: 15 - 00:45 0.50 PULL N DPRB DECOMP Pull chemical cutter to surface & verify fired - OK. Pull SWS off to side & LD sheave from top drive. 00:45 - 01 :00 0.25 PULL N DPRB DECOMP PU tubing string to 205 klbs to verify that pipe is cut and moving - OK. Broke back to 190-195 klbs up weight. 01 :00 - 02:00 1.00 PULL N DPRB DECOMP RD SWS wireline equipment. 02:00 - 03:00 1.00 PULL P DECOMP Pull & lay down landing jt, 5.5" hanger and 3 jts 5.5" tubing. 03:00 - 03:15 0.25 PULL P DECOMP PJSM for MU & running storm packer. 03:15 - 04:30 1.25 WHSUR P DECOMP Make up HES storm packer to 5.5" tubing and RIH on one stand 4" HT38 DP. Set packer at 75' BRT. Rotate right & release off packer and rack back stand. 04:30 - 04:45 0.25 BOPSUPP DECOMP Close blind rams & pressure test packer to 1000 psi - OK. 04:45 - 08:00 3.25 BOPSUPP DECOMP Nipple down BOP stack & set on stand. Prepare to change out 9-5/8" packoff & tubing spool. 08:00 - 12:00 4.00 WHSUR P DECOMP P/U BOP Stack, remove Spool, and pull seallpackoff assy. The bottom seal backup ring separated from the assembly. First attempts by Cameron to remove it were unsuccessful. Tool Pusher devised a way to safely pull it by hand without using extraordinary measures, one of which could have required gas sniffer, Hot Work Permit, and Fire Watch. 12:00 - 14:00 2.00 BOPSUF P DECOMP N/U Tubing Spool and test to 3,500 psi. 14:00 - 18:00 4.00 BOPSUF P DECOMP N/U BOPE. Install flowline to bell nipple. R/U remainder of lines. 18:00 - 20:00 2.00 BOPSUPP DECOMP Body test BOP stack & chk for leaks while waiting on AOGCC Rep to arrive. 20:00 - 23:00 3.00 BOPSUP P DECOMP Test BOPE & gas alarms. Valve on choke manifold leaking. 23:00 - 00:00 1.00 BOPSUP. N RREP DECOMP Chg out valve on choke manifold. 2/19/2005 00:00 - 05:00 5.00 BOPSUP P DECOMP Chase leak, determine Test Plug was leaking, RILDS solved the leak. 05:00 - 05:30 0.50 P DECOMP Service Top Drive. 05:30 - 09:30 4.00 BOPSUPN RREP DECOMP Koomey Annular Regulator Valve leaking. Repair Valve. Found to be washed out inside the body. 09:30 - 19:00 9.50 BOPSUPN DECOMP Wait on parts for Koomey Valves. Make repairs to Cuttings Drag Chain, service Skate and perform other PM activities on Rig. Printed: 3/7/2005 9:44:40 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/15/2005 Rig Release: 3/2/2005 Rig Number: Spud Date: 2/15/1989 End: Date From ~ To Hours . Task Code NPT Phase· DescriptionofOþerations · 2/19/2005 19:00 - 20:00 1.00 BOPSUPN DECOMP Reassemble Koomey valves. 20:00 - 22:00 2.00 BOPSUPP DECOMP Test BOPE. Test nos. 1, 2, 6, and 7 successful. 22:00 - 00:00 2.00 BOPSUPN DECOMP Koomey block Valve failed. Repairs started. Change out ejector rams on Pipe Skate. 2/20/2005 00:00 - 02:00 2.00 BOPSUPP DECOMP Complete repairs on Koomey Manifold Regulator Valve. Replace paddles on Cuttings Drag Chain, finish installing ejectors on Pipe Skate. 02:00 - 07:00 5.00 BOPSURP DECOMP Resume testing BOPE. All tests succesful and all tests witnessed by Jeff Jones, AOGCC, and by Well Site Leaders (Co Men). 07:00 - 08:00 1.00 BOPSURP DECOMP Pull Test Plug. Install Wear Ring. Bleed down lines. 08:00 - 09:00 1.00 BOPSURP DECOMP R/U to pull RTTS Storm Packer. RIH wi RTTS Flow Control Valve running tool, stab into Control Valve and M/U per HES hand's instructions. 09:00 - 10:00 1.00 BOPSUF P DECOMP POOH wi RTTS. Break out and UD Running Tool and packerlflow Valve. 10:00 - 12:00 2.00 BOPSUP P DECOMP Circulate Bottoms Up (5,200 Strokes, 63 SPM @ 160 psi) to warmup and recondition wellbore. P/U wt = 200K, SIO wt = 135K. 12:00 - 12:30 0.50 PULL P DECOMP R/U Camco SSSV Control Line Spooler. 12:30 - 15:00 2.50 PULL P DECOMP POH, LID, and number 5-1/2" tubing; spool control lines and count all bands. Break out SSSV and UD same. Recovered 59 SS bands of 62 installed. 15:00 - 00:00 9.00 PULL P DECOMP Resume POH 5-1/2" completion equpiment, 275 jts. out. 2/21/2005 00:00 - 01 :00 1.00 PULL P DECOMP Finish UD 289 jts 5-1/2" tubing & 12' stump. 01 :00 - 02:30 1.50 PULL P DECOMP RID tubing equipment & clean floor. 02:30 - 02:45 0.25 FISH P DECOMP Pre Job Safety Meeting with crew, Baker fishing & BP. 02:45 - 05:00 2.25 FISH P DECOMP M/U fish BHA #1: OIS Cut Lip Guide; OIS Bowl wi Mill Cut Packoff; Bumper Jar; Oil Jar; 12 ea 6-1/4" DCs; Pump Out Sub. 05:00 - 12:00 7.00 FISH P DECOMP RIH BHA #1 on 4" DP from Pipe Shed. 12:00 - 12:30 0.50 FISH P DECOMP Service Top Drive, Pipe Skate and Elevators. 12:30 - 17:30 5.00 FISH P DECOMP Continue RIH BHA #1 on DP from Pipe Shed. 17:30 - 18:30 1.00 FISH P DECOMP Wash-over fish. PU two singles. Engage fish, PU wt. 210K# up I 140K# down. 18:30 - 20:30 2.00 FISH P DECOMP Jar on fish wi max PU wt. 390K#, circulating pressure to 850 psi at 57 spm. Jarred loose. Circulate BU. Could not see any weight increase to indicate having entire fish down to seal assembly. 20:30 - 00:00 3.50 FISH P DECOMP POOH wi BHA#1, SLM. 2/22/2005 00:00 - 03:00 3.00 FISH P DECOMP POOH w/BHA#1, SLM. 03:00 - 04:00 1.00 FISH P DECOMP Rack back DC's. Recover severed portion of 5.5" tubing previously cut wi chemical cutter (27.05'). Pin had pulled out of box of pup jt above GLM at -11255', Stub was partially collapsed and split 2.15' up from pin end. 04:00 - 05:00 1.00 FISH P DECOMP LD fish & clear floor of tools etc. Discuss plan forward with Anch DE. Agree to run another chemical cutter and attempt a cut in the joint above the seal assembly. Contact SWS for E line unit. 05:00 - 11 :30 6.50 FISH N DPRB DECOMP Working on top drive, rig maintenance while waiting on E-line for next cut. Redressed overshot to 6-1/8"OD, plain control. Printed: 3/7/2005 9:44:40 AM ) ) BPEXPLORATION Qpèrations Su 1'1'I ITlé1ry Rèport . Legal Well Name: 12-32 Common Well Name: 12-32 Spud Date: 2/15/1989 Event Name: WORKOVER Start: 2/15/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/2/2005 Rig Name: DOYON 16 Rig Number: Date· Frohl- To· Hours ·Task Code NPT Phase 2/22/2005 11 :30 - 12:30 1.00 FISH N DPRB DECOMP PJSM. R/U Schlumberger for Gauge Ring CCL run to Top of Fish @ 11,717', then inside to CCL for Chemical Cut @ - 12,397', which is the middle of the first full joint and -20' above the Packer pup joint. 12:30 - 14:00 1.50 FISH N DPRB DECOMP RIH wi Schlumberger CCL and 2.75" Gauge Ring. Tag Stump @ 11,735' ELM. No restrictions found inside the 5-1/2". Tag IBP @ 12,420' ELM. Find top of pup @ 12,417' ELM on top of the packer. Next collar up is @ 12,376' ELM. Decide to make cut @ 12,395' ELM. 14:00 - 15:00 1.00 FISH N DPRB DECOMP POOH wi CCL I Gauge Ring. 15:00 - 20:00 5.00 FISH N DPRB DECOMP PJSM. M/U 2-strand String Shot and RIH to +1- fire across interval 12389' - 12401'. Fire string shot & POH for next run. 20:00 - 20:15 0.25 FISH N DPRB DECOMP PJSM. 20: 15 - 00:00 3.75 FISH N DPRB DECOMP MU chemical cutter (4.43" OD) and RIH. Cutter will not go below 12265' ELMD. Will not attempt to get too rough with chemical cutter. POH & prepare to run larger gauge ring. 2/23/2005 00:00 - 02:30 2.50 FISH N DPRB DECOMP POOH wi Chemical Cutter. LID onto Ground and Transferred to Schlumberger's Whale for Disassembly I Safeout. Observed Paraffin on Tool. 02:30 - 03:30 1.00 FISH N DPRB DECOMP M I U 4.5" Gauge Ring and Junk Basket. 03:30 - 04:30 1.00 FISH N DPRB DECOMP RIH wi 4.50" Gauge Ring and Junk Basket on E-Line, Tagged Up on Top of Tubing Stub at 11,735' ELMD. 04:30 - 05:00 0.50 FISH N DPRB DECOMP Made Several Attempts to Pass Through Top of Tubing Stub. 4th Attempt Successful, RIH Past Previous Restriction and Tagged Up on Top of IBP at 12,420' ELMD. 05:00 - 06:30 1.50 FISH N DPRB DECOMP POOH wi GR - JB to Surface. Junk Basket Full of Paraffin. 06:30 - 07:30 1.00 FISH N DPRB DECOMP Cleaned Paraffin Out of Junk Basket, Recovered 2 Gallons. 07:30 - 12:30 5.00 FISH N DPRB DECOMP RIH wi 4.50" Gauge Ring and Junk Basket on E-Line, Tagged Up at 11,620', Worked Through and Tagged Up on Top of IBP at 12,420' ELMD. POOH wi GR - JB to Surface. Recovered 1 SS Band and 1 Small Piece of Paraffin. 12:30 - 15:30 3.00 FISH N DPRB DECOMP Held PJSM, RID GR - JB, Schlumberger M I U and R I U 2 Strand String 180 grain Shot wi CCL. 15:30 - 16:30 1.00 FISH N DPRB DECOMP RIH wi String Shot on E-Line to 12,400' 16:30 - 17:00 0.50 FISH N DPRB DECOMP Pulled Up Hole and Tied into Previous CCL Log. Set CCL at 12,377.5', CCL to Top of String Shot Stand Off 11.5' Placed String Shot at 12,389' - 12,401'. Fired across interval f/12,389' to 12,401'. 17:00 - 19:30 2.50 FISH N DPRB DECOMP POOH to Surf. RDI RU for chem cut. 19:30 - 22:00 2.50 FISH N DPRB DECOMP Held PJSM for chem cut. RIH. Log on depth & made chern cut at 12395' ELMD. 22:00 - 00:00 2.00 FISH N DPRB DECOMP PJSM. POOH & UD chem cutter. SLB confirmed chem cutter fired. RD W/L tools. 2/24/2005 00:00 - 00:30 0.50 FISH N DPRB DECOMP Finished RID Schlumberger Equipment. 00:30 - 02:30 2.00 FISH N DPRB DECaMP Held PJSM. M I U BHA #2: 8-3/8" OIS wi Bowl and OIS Extension - Top Sub - Bumper Jars - Oil Jars - XO - 9 X 6-1/4" DC - XO - Accelerator Jars - Pump Out Sub - XO. Total Length 327.07'. 02:30 - 05:00 2.50 FISH N DPRB DECOMP RIH wi BHA #2 on 4" DP to 6,081'. 05:00 - 06:30 1.50 FISH P DECOMP Held PJSM. Slipped and Cut Drilling Line. 06:30 - 09:00 2.50 FISH P DECOMP RIH wi Fishing BHA #2 on 4" DP to 11,675'. 09:00 - 09:30 0.50 FISH P DECOMP M I U Top Drive, Engaged Pump, Pump Rate 4.5 bpm, 500 psi. Printed: 3/7/2005 9:44:40 AM ) ) BPEXPLORATION ···Operati ons .!)UnlrTlaryJFiep9rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/15/2005 Rig Release: 3/2/2005 Rig Number: Spud Date: 2/15/1989 End: . Date From -To Hours Ta.sk· Code NPT 2/24/2005 09:00 - 09:30 0.50 FISH P DECOMP String Weight Up 198,000#, String Weight Down 138,000#, RIH to 11,712', Engaged Tubing Fish, Stacked 10,000# on Fish to Ensure Grapples Engaged, Picked Up on Drill String, New String Weight Up 212,000#. Picked Up 30'. 09:30 - 11 :30 2.00 FISH P DECOMP Circulated Bottoms Up, 10 bpm, 2,250 psi, Observed Moderate Gas at Bell Nipple at Bottoms Up. Monitored Gas at Shakers, 1-2 ppm H2S, 9% LEL. Overboared 100 bbls of Paraffin and Crude Contaminated SW. Continued to Circulate Until Gas Cleared Up. 11 :30 - 12:30 1.00 FISH P DECOMP Shut Down Pumps and Monitored Well, Fluid Level Dropped 1', Then Became Static. No Gas. 12:30 - 16:30 4.00 FISH P DECOMP POOH wi 4" DP. 16:30 - 17:30 1.00 FISH P DECOMP POOH wi Fishing BHA #2, Broke Out Overshot From Top of Tubing Fish. 17:30 - 19:00 1.50 FISH P DECOMP Held PJSM. R I U 5-1/2" Tubing Handling Equipment. Broke Out & UD 14 jts 5-1/2" tubing plus cut jt = 20.87' + 3 GLM. (Total length 670.88' SLM). 19:00 - 19:30 0.50 FISH P DECOMP RID 5-1/2" tools 19:30 - 22:00 2.50 FISH P DECOMP Held PJSM. M I U BHA #3 3-3/8 "OD OIS, XO, XO, Shear Pin Sub, 2 x 2-7/8" PAC DP, XO, XO, 9-5/8" Casing Scraper, Bit Sub XO, Bumper Jar, Oil Jar, Pump Out Sub, XO, 9 x 6-3/16" DC, XO,XO Total Length: 387.42' 22:00 - 00:00 2.00 FISH P DECOMP RIH wi BHA #3 2/25/2005 00:00 - 05:30 5.50 FISH P DECOMP RIH wi BHA #3 on 4" DP to 12,375'. 05:30 - 07:00 1.50 FISH P DECOMP M / U Top Drive, Engaged Pump, 4.5 bpm, 610 psi. Established Parameters: String Weight Up 210,000#, String Weight Down 145,000#. Washed Down from 12,375' to 12,412', Tagged and Latched Up on IBP at 12,412', Pump Pressure Increased to 1,100 psi, Slowed Pump to 2 bpm, 800 psi. Picked Up on Drill String w/1 0,000# Overpull, RIH 2' Past Setting Depth, Pump Pressure Increased to 1,600 psi, Shut Down Pump. Picked Up on Drill String w/1 0,000# Overpull, Waited for IBP Element to Relax. Circulated 1 bpm, 200 psi Through Grapples While Waiting on Element to Relax. Fluid Losses 100 bph. 07:00 - 08:00 1.00 FISH P DECOMP Lost 5,000# on Overpull, RIH to Place 9-5/8" Casing Scraper at 12,348'. Broke Off Connection, Dropped Opening Dart for Pump Out Sub. M I U DP Connection and Pumped Dart onto Seat. Pressured Up to Shear Sub Open at 2,000 psi. Pressured Up to 3,500 psi x 4 without Success. POOH, B I 01 Stand, Blew Down Top Drive. 08:00 - 14:30 6.50 FISH P DECOMP POOH wi Wet 4" DP. Cannot Keep Hole Full, Pumped Double DP Displacement While POOH. Total Fluid Lost to Hole 315 bbls. 14:30 - 17:30 3.00 FISH P DECOMP POOH, B I 0 and LID BHA. Recovered IBP. 17:30 - 21 :00 3.50 FISH P DECOMP Held PJSM. M I U BHA#4 3.7" OD 5 Bladed Junk Mill, JB, Shear Pin Sub, 5 jts. 2-7/8" PAC DP, XO, XO Bumper Jar, Oil Jar, Pump Out Sub, XO, 9- 6-3/16" X 2-3/4" DC, XO, XO. Hanging on Shear Pin Sub: 8-3/8" OS Lip Guide, OS Bowl, OS Extension, Top Sub & Shear Out Sub Total Length = 487.43' SLM 21 :00 - 00:00 3.00 FISH P DECOMP RIH w/BHA#4. Observed no returns. Pumped Double Pipe Displacement while RIH. Fluid Lost to Hole while RIH: 100bbl. Printed: 3nt2005 9:44:40 AM ) ) BPEXPLORATION Oþéréltiol1S Summary· Report Þage 6 of8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/15/2005 Rig Release: 3/2/2005 Rig Number: Spud Date: 2/15/1989 End: Date From·- To· Hours Task Code· NPT Phase Description.of Operations. 2/26/2005 00:00 - 01 :00 1.00 FISH P DECOMP RIH wi BHA #4 to 12,370'. 01 :00 - 04:00 3.00 FISH P DECOMP M I U Top Drive, Engaged Pump, 3 bpm, 50 psi. Established Parameters, String Weight Up 225,000#, String Weight Down 155,000#, Rotating Weight 183,000#. Washed Down from 12,370' to Top of Tubing Stub at 12,382'. OIS Shear Sub had Sheared While RIH. RIH Tagged FasDrill Plug at 12,448' DPM. Milled and Pushed FasDrill Plug, WOM 10,000#, 70 RPM, Torque 9,000 ft-Ibs, 4.5 bpm, 200 psi. Pushed FasDrill Plug Out of WLEG at 12,520' DPM to 12,548' DPM. Total Fluids Lost While Milling, 755 bbls. 04:00 - 10:30 6.50 FISH P DECOMP POOH wi 4" DP. Pump Double DP Displacement While POOH. 10:30 - 11 :30 1.00 FISH P DECOMP PJSM, POOH wi BHA #4, B I 0 and LID Jars, Bumper Jars. 11 :30 - 12:00 0.50 FISH P DECOMP RID 4" Handling Equipment, R I U 2-7/8" Handling Equipment. 12:00 - 13:30 1.50 FISH P DECOMP POOH, B I 0 and LID 2-7/8" DP. 13:30 - 14:00 0.50 FISH P DECOMP RID 2-7/8" Handling Equipment, R I U 4" Handling Equipment. Cleared and Cleaned Rig Floor. 14:00 - 15:30 1.50 FISH P DECOMP Held PJSM. M I U BHA #5: 8-1/2" Dress-Off Shoe wi 4.87" Inside Dressing Mill - 2 x 8-1/8" Wash Pipe Extensions - Boot Basket - Bumper Jars - Oil Jars - XO - 12 x 6-1/4" DC - XO- XO. Total Length 411.71'. 15:30 - 19:30 4.00 FISH P DECOMP RIH wi BHA #5 on 4" DP to 12,375'. 19:30 - 20:00 0.50 FISH P DECOMP M I U Top Drive. Engaged Pump, 3 bpm, 50 psi. Established Parameters, String Weight Up 230,000#, String Weight Down 150,000#, Rotating Weight 160,000#. 80 rpm, Torque 13,000 ft Ilbs. Tagged Top of 5-1/2" Tubing Stub at 12,382'. Dressed Top From 12,382' to 12,382.5'. 0% Returns While Dressing Off Tubing. 20:00 - 00:00 4.00 FISH P DECOMP Held PJSM. B 10 and Blew Down Top Drive, LID DP from 12,382'. Pumped 6 bbls SW Down Hole Every 15 minutes. Simultaneously, Tested Choke Manifold; Low Test 250 psi, High Test 3,500psi. Each of six pressure tests held f/5 minutes wi No Leaks or Pressure Loss. AOGCC Rep Chuck Scheve Waived Witness of Test. Company Rep Bruce Tate Witnessed Test. 2/27/2005 00:00 - 08:00 8.00 FISH P DECOMP LID Drill Pipe. Pumped 6 bbl SW Down Hole Every 15 minutes. 08:00 - 11 :00 3.00 FISH P DECOMP POOH, B I 0 and LID BHA, Pumped 6 bbls SW Down Hole Every 15 Minutes. 11 :00 - 12:00 1.00 FISH P DECOMP Cleared and Cleaned Rig Floor. Opened Blind Rams and Pumped 6 bbls SW Down Hole Every 20 Minutes. 12:00 - 13:30 1.50 BOPSUP P RUNCMP Held PJSM, R I U Equipment to Test BOPE. Pulled Wear Bushing, Ran and Set Test Plug. 13:30 - 18:30 5.00 BOPSUP P RUNCMP Attempted to test BOPE, manual choke valve failed. N I D Manual Choke Valve, Rebuilt and Re-Installed same. 18:30 - 21 :30 3.00 BOPSUP P RUNCMP Held PJSM. Tested BOPE. Tested Upper Rams, Lower Rams, Blind Rams, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 3,500 psi High 1250 psi Low. Tested Annular Preventer to 3,500 psi High 1250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held wi No Leaks or Pressure Loss. Witnessing of BOPE Test Waived by AOGCC Rep. Chuck Scheve. All Tests Witnessed by BP Drilling Supervisor. 21 :30 - 22:00 0.50 BOPSUP P RUNCMP Pulled Test Plug, RID BOP test equipment. 22:00 - 23:30 1.50 RIGU P RUNCMP Changed out bails. RIU power tongs, elevators, compensator Printed: 3/7/2005 9:44:40 AM ) ) BPEXPLORATION OperaJiønsSurnl11é1ry Report Date Fröm~T6 . HoUrs Task Code NPT 2/27/2005 22:00 - 23:30 1.50 RIGU P 23:30 - 00:00 0.50 RUNCOrvP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/28/2005 00:00 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 23:30 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 21.00 RUNCOMP 0.50 RUNCOMP 0.50 RUNCOMP 1.50 RUNCOMP Start: 2/15/2005 Rig Release: 3/2/2005 Rig Number: Phase Spud Date: 2/15/1989 End: RUNCMP and torque turn equipment. RUNCMP Held PJSM. M I U 4-1/2" 12.6# 13Cr85 Fox Tail Pipe Assembly: WLEG I XN Nipple Assy - 1 Joint Tbg - Lower X Nipple Assy - 9-5/8" x 4-1/2" Baker S-3 Packer Assy - Upper X Nipple Assy. Bakerlcked All Connections Below Packer. PI U Joints wi Compensator, Torque Turned All Connections. M I U Torque fl Fox Connections 4,280 ft Ilbs, M I U Torque fl TC II Connection 2,800 ft Ilbs. Pumped 6 bbls SW Down Hole Every 30 Minutes. Doped Connections wi Jet Lube Seal Guard. RUNCMP Held PJSM. RIH wi 4-1/2" 12.6# 13Cr85 Fox Tubing, 385 jts & 10' pup. P I U Joints wi Compensator, Torque Turned All Connections. M I U Torque fl Fox Connections at 4,280 ft Ilbs. Pumped 6 bbls SW Down Hole Every 30 Minutes. Doped Connections wi Jet Lube Seal Guard. RUNCMP RID Compensator, M I U Circulating Head to #386. M I U #386 to Tubing String. RUNCMP Engaged Pump 3 bpm, 50 psi. Washed down, Observed 1,000# - 2,000# Stack Out on 5-1/2" Tubing Stub at 12,377' TMD. Collar No-Goed at 12,385' TMD. Stacked 10,000# on Collar No-Go, PI U and Repeated No-Go x 2 To Ensure Proper Depth. Lined Up to Pump Down 9-5/8" x 4-1/2" Annulus. Engaged Pump, 3 bpm, 50 psi. No Returns to Surface. RUNCMP RID Circulating Head and Lines. LID Jt #386 and 10' Pup Jt. M I U Tubing Hanger and Landing Jt. Landed Hanger in Tubing Head. Tubing Spaced Out wi WLEG at 12,381' TMD. 4' Inside 5-1/2" tubing Stub. Completion Equipment Set At The Following Depths: Item Length Depth WLEG I XN Nipple wi RHC Sleeve Assy 22.36' 12,381.00' 1 Jt 4-1/2" 12.6# 13Cr85 Fox Tbg 30.88' 12,327.76' Lwr X Nipple Assy 20.89' 12,306.87' 9-5/8" x 4-1/2" S-3 Packer Assy 24.30' 12,282.57' Upper X Nipple Assy 20.89' 12,261.68' 62 Jts 4-1/2" 12.6# 13Cr85 Fox Tbg 1,947.66' 10,314.02' #5 GLM Assy wi DCR Shr Valve 28.13' 10,285.89' 24 Jts 4-1/2" 12.6# 13Cr85 Fox Tbg 755.30' 9,530.59' #4 GLM Assy 28.15' 9,502.44' 64 Jts 4-1/2" 12.6# 13Cr85 Fox Tbg 2,014.82' 7,487.62' #3 GLM Assy 28.20' 7,459.42' 84 Jts 4-1/2" 12.6# 13Cr85 Fox Tbg 2,641.04' 4,818.38' #2 GLM Assy 28.24' 4,790.14' 37 Jts 4-1/2" 12.6# 13Cr85 FoxTbg 1,163.12' 3,627.02' #1 GLM Assy 28.06' 3,598.96' 48 Jts4-1/2" 12.6# 13Cr85 FoxTbg 1,508.21' 2,090.75' X Nipple Assy 20.58' 2,070.17' 65 Jts 4-1/2" 12.6# 13Cr85 Fox Tbg 2,045.27' 24.90' Printed: 3/7/2005 9:44:40 AM ) ) BP EXPLORATION . Qperéttions> $l.Immary· Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-32 12-32 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/15/2005 Rig Release: 3/2/2005 Rig Number: Spud Date: 2/15/1989 End: Date From... To Hours . Task Code NPT Phase . De~criptionof Operations 2/28/2005 22:00 - 23:30 1.50 RUNCOMP RUNCMP 23:30 - 00:00 0.50 RUNCOMP RUNCMP 00:00 - 01 :30 1.50 RUNCOMP RUNCMP 01 :30 - 05:00 3.50 RUNCOMP RUNCMP 05:00 - 08:30 3.50 RUNCOMP RUNCMP Tubing Hanger 3.81' 21.09' RID 4-1/2" Tubing Handling Equipment, Cleared and Cleaned Rig Floor. RILDS, R I U and Pressure Tested Circulating Lines to 3,500 psi. OK. Pumped 600 bbls of 140 degree Corrosion Inhibitied SW Down 9-5/8" X 4-1/2" Annulus. 3 bpm, 50 psi. No Returns. PJSM wi BOT and All Rig Personnel on Setting Packer and Testing Tubing. Broke Out Head Pin, Dropped Balli Rod Assy. Allowed Balli Rod Assy to Fall On Seat. M I U Head Pin, Pressured Up on Tubing to 2,500 psi to Set Packer, Increased Pressure to 3,500 psi, Tested Tubing f/30 minutes. Bled Tubing Pressure to 2,000 psi. Tested 9-5/8" X 4-1/2" Annulus to 3,500 psi f/30 minutes. Bled Tubing Pressure Down and Sheared DCR Valve, Valve Sheared at 2,600 psi Differential. Bled Down All Pressures. 3/1/2005 08:30 - 09:00 0.50 RUNCOMP RUNCMP Pumped Remaining 40 bbls 140 deg SW wi Corrision Inhibitor Down Annulus, Took Returns Up Tubing, Pump Rate 3 bpm, 290 psi. Pumped Down Tubing and Took Returns off of Annulus, Pump Rate 3 bpm, 310 psi. DCR Valve Fully Sheared. 09:00 - 10:00 1.00 WHSUR P TUBHGR RID Circulating Head and Lines, B I 0 and LID Landing Joint. Blew Down All Lines. Drained Stack, Set TWC and Tested From Below to 1,000 psi. 10:00 - 17:00 7.00 BOPSUP P RUNCMP Held PJSM. N I D BOPE, Removed Pipe Rams fl Reconfiguration of BOP Stack. Remove Kill Line, Choke Line HCRI Manual Valves. Set back BOPE's on pedistal and secure same. 17:00 - 20:30 3.50 WHSUR P RUNCMP PJSM- Install Adaptor Flange, Production Tree and Test t/ 5,000 psi. wi Diesel 20:30 - 21 :30 1.00 WHSUR P RUNCMP R/U DSM Lubricator, Pull TWC, RID Lubricator 21 :30 - 22:30 1.00 WHSUR P RUNCMP PJSM-R/U Little Red for IA Freeze Protection. Found frozen line in Hot Oil Unit Heating Coil. 22:30 - 00:00 1.50 WHSUR N FLUD RUNCMP Troubleshoot frozen line and thaw same. 3/2/2005 00:00 - 01 :30 1.50 WHSUR P OTHCMP Displace Seawater in IA with 160 bbls. of Diesel for Freeze Protection @ 2bpm @ 150 psi 01 :30 - 02:30 1.00 WHSUR P OTHCMP U-Tube Diesel from IA to Tubing 02:30 - 04:00 1.50 WHSUR P OTHCMP RID & BID Circulating lines. Set BPV and Test from below to 1,000 psi. Secure the Tree and Cellar. Released Rig @ 0400 hrs on 3-2-05 Printed: 3/7/2005 9:44:40 AM TREE :=., 4;1/16 X 5M GEN 4 WELLHEAD:= MCEVOY AcfÜÃ'TÔvFr;,;,'v AXELSON '¡;¿Ëf'ELE\Ï;;;"" . " .., "m" 74> BF. ELEV := ~KOF);'WW^""""'^""V""^""""^"^""'906" Max Angie';' ' 57 @ 7900' Daìüm'iV10;';"""" """"1^3019ì 'ÖatUnïw6;;;" 8800' SS ) 113-3/8" CSG, 68#/72#, K-55/L-80, ID:= 12.415" 1-1 4434' Minimum ID = 3.725" @ 12369' 4-1/2" OTIS XN NIPPLE ITOPOF 5-1/2" TBG STUB (02/26/05) 1-1 12377' 14-1/2" TBG, 12.6#, 13CR80, .0152 bpf, 10 = 3.958" 1-1 12381' I 5-1/2" TBG, 17#, L-80, .0232 bpf, 10:= 4.892" 1-1 12442' TOPOF 4-1/2" TBG 1-1 12443' I TOP OF 7" LNR 1-1 12480' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10:= 3.958" 1-1 12540' 1 19-5/8" CSG, 47#, L-80, 10:= 8.681" 1-1 12794' ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/12/89 A NGLE AT TOP ÆRF: 43 @ 12792' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12792 - 12822 0 07/10/94 3-3/8" 4 12930 - 12948 0 02/13/91 3-3/8" 4 12960 - 12980 0 12/26/92 3-3/8" 4 12992 - 13033 0 06/05/89 3-3/8" 4 13037 - 13072 0 06/05/89 3-3/8" 4 13076 - 13111 0 06/05/89 3-3/8" 4 13116 - 13126 0 06/05/89 3-3/8" 4 13130 - 13140 0 06/05/89 I PBTD 1-1 13454' 17" LNR, 29#, L-80, .0371 bpf, 10:= 6,184" 1-1 13499' I TO 1-1 13500' DA TE REV BY COMMENTS 03/22/89 ORIGINAL COM PLEfION 03/05/05 KCF/TLH RWO 03/17/05 DTRlPJC GL V C/O DA TE REV BY 12-32 . . L - :8: I 1 I I I :8:- . . Z ~ J ~ \ ! .. I !L~ I ,- I J: I T , - COMMENTS ~ ) SAFETY NOTES: IA x OA COMM. OA DOWN-SQZ'D. *** 4-1/2" CHROME TBG *** 2080' r-14-1/2" HES X NIP, ID = 3.813" 1 GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 5 3609 2990 48 MMG DMY RK 0 02/28/05 4 4800 3793 51 MMG DOME RK 16 03/17105 3 7469 5393 53 MMG SO RK 20 03/17/05 2 9512 6588 51 MMG DMY RK 0 02/28/05 1 10296 7086 51 MMG DMY RKP 0 02/28/05 12272' 1-14-1/2" HES X NIP, 10 = 3.813" 1 12292' r-19-5/8" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 12317' r-14-1/2" HES X NIP, 10:= 3.813" 1 12369' r-14-1/2" HES XN NIP, ID:= 3.725" 12381' 1-14-1/2" WLEG, 10 = 3.958" 1 12423' - 9-5/8" X 5-1/2" BAKER FB-1 PKR 1 12425' - 5-1/2" BAKER SEAL BORE EXT 1 12442' 1- 5-1/2" X 4-1/2" XO (7-5/8" X 4-112" XO BELOW MILLOUT EXT.) 12527' 1-14-1/2" OTIS XN NIP, 10:= 3.725" 1 12540' 1--14-1/2" WLEG 1 12513' 1-1 ELMO TT LOGGED 12/03/89 1 I -12548 1- 5-1/2" FASDRILL PLUG, MILLED OUT & PUSHED TO THIS DEPTH ON 02/26/05 I 13124' 1- 10' OF 1.25" STEM W/1.188" FN & BOX END BROKEN OFF (LOST 04/23/96) PRUDHOE SA Y UNIT WELL: 12-32 ÆRMITNo: 1890110 API No: 50-029-21910-00 SEC 17, T10N, R15E, 1909,03' FEL &648.29' FNL BP Exploration (Alas ka) 12-32 (PTD # 1890110) Classified as Problem Well ) ) Subject: 12-32 (PTD #1890110) Classified as Problem Well \ From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> oJil-- r; \' Date: Tue, 29 Mar 2005 06:01:10 -0900 \~~'<l To:: "Gerik, Bob,G(PRA)" <GerikBG@BP.com>,ItGPB,FSl/SIP/STPArea. Mgr" <qPBFSJTL@BP.coro>,."OPB, FS1 DS Ops Lead" <QPBFS1DSOpsLead@BP.com>, "Rossb~rg, R Ste?ven" <RossbeRS@BP.com>, "NSU,ADWWell Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>,· "OPE, Wells Opt Eng" <GPBWèllsOptEng@BP.ëom>, "AOGCC Jim Regg (E:mail)" <jim_regg@adniin.st~te.ak.us>, "AÖOCC Winton Aubert (E.;.mail) " <winton_aubert@admin.state.ak.us>,·"NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com.>" "GPB, FSIDS 12 Operator" <G~BFS' IDS 120perator@BP.col11> . , CC:"NSU,ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Reeves, DdnaldP" <ReevesDf@BP .com>, IIMielke,· RobertL." . <robert.mit.úke@BP.com> All, Well 12-32 (PTD #1890110) has been found to have sustained casing pressure on the OA. The TIO's on 03/28/05 were 260/1220/1220. A TIFL has been conducted and a MITOA is scheduled for waiver evaluation. The plan forward for this well is as follows: 1. DHD: TIFL - PASSED 2. FB: MITOA to 3000 psi 3. WAV: Waiver for IAxOA comm The well has been classified as a Problem well. Please call if you have any questions. Thank you, }I nna (j)u6e Well Integrity Coordinator 2.0 \') ~~ GPB Wells Group SCANNED APR 1 4· u.) Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 « 12-32.pdf» Content-Description: 12-32.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 3/29/2005 4:44 PM BP Exploration (Alaska) PRUDHOE SA Y UNIT WELL: 12-32 PffiMITNo: 1890110 API No: 50-029-21910-00 SEC 17. T10N, R1SE, 1909.03' FEL & 648.29' FNL I 13124' -10'OF1.25"STEMW/1.188"FN&SOX END BROKEN OFF (LOST 04/23/96) I -12548 1- S-1/2" FASDRILL PLUG, MILLED OUT & PUSHED TO THIS DEPTH ON 02/26/05 COMMENTS -, - ., I I I 12272' ~14-V2" HES X NIP, 10 = 3.813" J Z ~ I 12292' J-19-S/8" X 4-1/2" BKR S-3 PKR, 10 = 3.87S" J I . I 12317'.1-14-1/2" HES X NIP, ID = 3.813"1 I I I 12369' 1-14-1/2" HES XN NIP, 10 = 3.725" \, I 12381' 1--14-1/2" WLEG, ID = 3.958" I Z :8:- 12423' - 9-5/8" X 5-1/2" BAKER FB-1 A<R I 12425' - 5-1/2" BAKER SE;AL BORE EXT \ I I 12442' 1- 5-1/2" X 4-1/2" XO (7-5/8" X 4-112" XO BELOW MILL OUT EXT.) .. I I I I 12527' 1-i4-1/2" OTIS XN NIP, ID = 3.725" I 12540' hi4-1/2" WLEG I 12513' JiELMO TT LOGGED 12/03/891 DA TE REV BY DA TE REV BY COMMENTS 03/22/89 ORIGINAL COM PLETION 03/05/05 KCF/TLH RWO 03/17/05 DTRlPJC GL V C/O I PBTD 1--1 13454' I 7" LNR" 29#, L-80, .0371 bpf, ID = 6.184" l-i 13499' [Ð-i 13500' ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/12/89 ANGLE AT TOP PERF: 43 @ 12792' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12792 - 12822 0 07/10/94 3-3/8" 4 12930 - 12948 0 02/13/91 3-3/8" 4 12960 - 12980 0 12/26/92 3-3/8" 4 12992 - 13033 0 06/05/89 3-3/8" 4 13037 - 13072 0 06/05/89 3-3/8" 4 13076 - 13111 0 06/05/89 3-3/8" 4 13116-13126 0 06/05/89 3-3/8" 4 13130 - 13140 0 06/05/89 ~ 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 127.94' µ GA S LIFT MA NDRELS ST MD TVD DEV TY PE VLV LATCH PORT DATE 5 3609 2990 48 MMG DMY RK 0 02/28/05 4 4800 3793 51 MMG DOME RK 16 03/17/05 L ' 3 7469 53~¡3 53 MMG SO RK 20 03/17/05 - 2 9512 6588 51 MMG DMY RK 0 02/28/05 1 1029B 7086 51 MMG DMY RKP 0 02/28/05 2080' ~14-1/2" HES X NIP, ID = 3.813" I ')AFETY NOTES: IA x OA COMM. OA DOWN~SQZ·D. .1<** 4~1/2" CHROME TBG*'Þc-lt I I 12 -32 14-1/2" TBG. 12.6#, L~80, .0152 .bpf, ID == 3.958" -f 12540' l TOP OF 7" LN~I-I .. 12480' [TOP OF 5-1/2" TBG STUB (02/26/05) 1-1 12377' 14-1/2" TBG, 12.6#, 13CR80, .0152 bpf, ID'" 3.958" 1-1 12381' 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892"1-1 12442' I TOP OF 4-1/2" TBG -I 12443" Minimum ID = 3.725" @ 12369' 4-1/2" OTIS XN NIPPLE 113-3/8" CSG, E¡8#/72#, K-55/L-80, 10 = 12.415" l-i 4434' ) TREE= 4-1/16 X 5M GEN 4 WELLHEAD == MCEVOY ACTUA TOR = AXELSON "1<'8. äÈ\l == 74' SF. ELEV = KOP ;'''' 900' Max Angle == 57 @ 7900' Ö.iiiürnMÖ;;" ... ·····'13Ò1'9; DatÚn,TVO;S8ÒÒi 55 FW: Initial BOPE Test for Drillsite 12, Well 32--Doyon 16 ) Subject: FW: Initial BOPE Test for Drillsite 12, Well 32--Doyon 16 From: "Rooney, Michael S (ORBIS ENGINEERING)" <roonms@BP.com> Date: Thu, 17 Feb 2005 17:23:10 -0900 . .. . . T~: nAOGCC~Anchorage (E-mailr' <jim~regg@admin.state.ak.l;1s> , , <,' Cc: tlChari~Paul (PRAt <charipl@BP.com:>~"NSU, ADW:bdgRig)6'" , - ' , , <1'tSUADWDrlgRig16@BP.com>, ,"N"SU~ADW Drlg '16 TLCIt <NSUADWDrlg16TLC@:Br.Corif>:, ) , v~~~(:Y\'\ Jirn---My apology for mis-naming the well we are currently working on. It is Drillsite 12, well 32. I have no excuses, and no physical anomalies, just an errant finger on the keyboard. We were successful in the first phase of testing the BOPE per the plan below. However, we could not pull the tubing, and have since run a Gage Ring and CCL to an obstruction @ 11, 715' E-Line Msmt. We are currently RIH w/ a string shot to cover 11,690', the depth we wish to chemically cut the tubing. Once we chemically cut the tubing we will pull the hanger and three joints of tubing. We will then set the Storm packer as previously planned so that we can change out the tubing head and packoff to enable a full BOPE test once we re-Iand the BOP stack per the pIa, below. Again my apology for the mix-up with the well name--it is Drillsite 12, well 32. Mike Jim---We will be testing our BOPE within the next few hours and are requesting a variance in theehtire f3equenceof tests. Our plan is as follows: p/U Landing Joint and install in hanger. Perform full body -test and test, all 'spools ~ Choke manifold test for valves, 12, 13, and 14. Pull hanger to the floor plus three full joints. P/U Storm Packer and set one stand below wellhead and test to 1,000 psi. N/D BOPE. Change-out packoff and the tubing spool. N/U BOPE and perform full BOPE test. There are two plugs downhole: a 4-1/2" Halco FasDril1 set @ 12,466', which was leaking. Another plug, a 3-3/8" IBP is set and tested in the 5-1/2" tubing @ l2,431'. We circulated out the freeze protect fluid and completely circulated the wellbore down to a part in the 5-1/2" tubing @ 11,692'. The well was dead when we first bled it down and is dead now after full wellbore circulation. Fluid level is at the surface. Please let me know if you have any further questions. Mike Rooney, Well Site Leader, Doyon 16 SCANNED FEB 222005 1 of 1 2/18/2005 8:48 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~1~ Commissioner Tom Maunder, P. i. Supervisor DATE: May 7, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, May 7, 2001_: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summary.: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Prudhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 Well Permit Separ Set L~ Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLE 12-01 1790230 ......... , , 12-02 1790320 12-03 17'90410 160 150 150 ' e ' ' P " OIL 12-04A 1811870. '160 '150 150 P' P OiLi 12-05 1790550 12-06A 1920540 160: 150 150 P P OIL , , , 12-07A 1811750 160' 150 140 P P OIL ,, ,, I 15'08B 1811670 160! 150 140 P P OIL 15-09 '1800930 ' '160 " 150 125 ' e P '" OIL , , , 12-10A 1920890 160 150 150 P P OIL 12-11 , 1810730 12'12 1810830 160 150 90 ..... P 4 " OIL 12-13B 1960170 160 150 150 P P OIL 12-14A 1981460 160 150! 150 P P OIL 12-15 1830320 160 1501 1501P P OIL 12-16A 1931480 ' 160 ' 1501 15'01' P .... P ' OIL 12-1.7 1830040 160' 150 150i P P ' OIL . 12-18 1822060 160 150 150 P P OIL ,, 12-19 1821980 12-20 1821910 12-21 1840480 ...... 12-22 ' 1840600 160 i50 " 125' P P " oil , , 12-23 1840580 12-25 1831660 12-26 1840140 "'160 150 '125 P P 'OIL 12-27A 1990390' ,, 12-28A 199033~i 160 150 ''170 P P " OIL 12-29 18403201 12-30 1881420 12-31 ........ ~,~, .i~ ~,~!890010 ~:!;;~:::ili~!:ii~; 890110 ,. ,1601 .... i 50 ~50' ' e' P . " , ," . 12-33 1890100 12-34 1941370 'i6o 150 '15o ' P' P OIL .... ,, 12-35 1951300 160 150 100 12-36 1951580 160 1501 150 '"P P ,, RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p4~C.S Well Number Wells: Permit Number 21 Remarks: Separ Set PSI PSI Components: L/P Test Trip Code 42 Failures: i i';;i ~'{'~:~est ~I ..... 'Date ........ lollI WAG' CodeI CodeI Passed l aASo CVCL 1 Failure Rate: 2.38% ['-'! 90 Day Surface Safety Valve on well 12-12 had slow leak when pres. s,ure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 P M C:LORlqVlFILM.DOC E E L E W A T E R IA L U N D ER TH IS M A R K ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMI~IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing ~ Alter casing ~ Repair well ~ Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1030' FSL, 125' FWL, Sec 17, T10N, R15E, UM. At top of productive interval 741' FNL, 2305' FEL, Sec 16, T10N, R15E, UM. At effective depth 653' FNL, 1956' FEL, Sec 16, 'I'10N, R15E, UM. At total depth 645' FNL, 1924' FEL, Sec 16, T10N, R15E, UM. 5. Type of Well Development X~ Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-32 9. Permit number/approval number 89-11 10. APl number 50 - 029-21910 11. Field/Pool Prudhoe Bay Oil Pool RF(,F/VFn AUG 1 6 1996 12. Present well condition summary Total depth: measured 13500 feet true vertical 9222 feet Effective depth: measured 13133 feet true vertical 8883 feet Junk(measured) Alaska 0il & Gas Cons. Commission Anc~horaoe Casing Length Size Cemented Measured depth True~ertical depth Conductor 80' 20" 2150# Poleset 110' 110' Surface 4400' 13-3/8" 2500 Sx CS III, 600 Sx CI G, & 4434' 3554' 120 Sx CS II (top job) Production 12762' 9-5/8" 500 Sx CIG 12793' 8708' Liner 1019' 7" 350 Sx CIG 13499' 9221' Perforation depth: measured 12792 - 12882'; 12930 - 12948'; 12960- 12980'; 12992 - 13033'; 13037 - 13072'; 13076 - 13111'; 13116 - 13126'; 13130- 13140' true vertical 8707 - 8729'; 8734 - 8747'; 8756 - 8771'; 8779 - 8810'; 8812 - 8838'; 8841 - 8867'; 8871 - 8878'; 8881 - 8888' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 12442' MD; 4-1/2", 12.6#, L-80, PCT @ 12540' MD. Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 12423' MD; Camco BaI-O SSSV @ 2221' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut In -- 1048 7239 7424 Tubing Pressure 26O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~.,~ /)4'1 · ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 12-32 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE OF 13-3/8" CASING LEAK 5/8/96: RIH & set a PXN plug in the tubing tail XN nipple at 12527' MD. 6/30/96: A 13-3/8" Casing Leak Cement Squeeze was performed as follows: MIRU & PT equipment. Squeezed a 13-3/8" casing leak by pumping the following sequence down the 13-3/8" annulus: Pumped: a) 500 bbls Hot Seawater, followed by b) 150 bbls Arctic Set I Cement w/cellophane flakes & 20 ppb aggregate, followed by c) 50 bbls Arctic Set I Cement w/cellophane flakes, followed by d) 100 bbls Neat Arctic Set ! Cement, followed by e) 70 bbls Crude displacement, followed by f) 15 bbls Diesel, followed by g) Shutdown. Attained 850 final whp following 300 psi break & hesitation of squeeze during Crude displacement. Left 850 psi on 13-3/8". Rigged down. 7/1 1/96: RIH & pulled the PXN plug (above). 7/22/96: M ITOA to 2000 psi passed. 7/29/96: RIH & tagged PBTD at 13133' MD. Returned the well to production w/lift gas & obtained a valid welltest. ,~-. STATE OF ALASKA ~ ALASKA _ AND GAS CONSERVATION CC AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1030' FSL, 125' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-32 9. Permit number/approval number 741' FNL, 2305' FEL, Sec. 16, T10N, R15E, UM At effective depth 653' FNL, 1956' FEL, Sec. 16, T10N, R15E, UM At total depth 645' FNL, 1924' FEL, Sec. 16, T10N, R15E, UM 89-11 10. APl number 50 - 029-21910 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 13500 feet 9222 feet Plugs(measured) PBTD Tagged @ 13124' MD (7/10/94) Effective depth: measured 13124 feet true vertical 8951 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2150 # Poleset 110' 110' 2500 sx CS III & 600 sx CI G, Top job w/120 4434' 3554' Sudace 4400' 13-3/8" sx cs II Production 12762' 9-5/8" 500 sx CIG 12793' 8708' Liner 1019' 7" 350 sx CIG 13499' 9221' Perforation depth: measured 12792-12882'; 12930-12948'; 12960-12980'; 12992-13033'; 13037-13072'; 13076-13111'; 13116-13126'; 13130-13140' true vertical 8707-8729'; 8734-8747'; 8756-8771 '; 8779-8810'; 8812-8838'; 8841-8867'; 8871-8878'; 8881-8888' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 12442' MD; 4-1/2", 12.6#, L-80, PCT tail @ 12540' MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2221' MD; Baker FB-1 Packer @ 12423' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation RECEIVED ,~' [-~P - '1 1994- Representative Daily Average Production or Injection Data ,,~t~¢,a 0ii ~ ,~,o ,~,~,,o. ,.,,,,,,,,,,oo .... Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Ancl~rt~ Pressuro 488 1005 5195 -- 230 896 2128 6501 -- 252 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x. Gas .... Suspended .. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '//~~\~_ ~ ~ Title Sr. O/A Engineer Form 10-404 Rev 06/15/88 1193/13 CC: KZ, JWP Date '~1 ~Sb i¢i,-{- SUBMIT IN DUPLICATE 12-32 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/8/94: RIH & tagged PBTD at 13105' MD. 7/1 0/94: MIRU & PT equipment. RIH w/perforating gun & tagged PBTD at 13124' MD, then PU & shot 30' of add perforations as follows: Added perforations: 12792 - 12822' MD (Sag) Ref. Log: BHCS 3/12/89. Used a 3-3/8" carrier, & shot 4 spf, at 180 degree phasing, at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/lift gas & obtained a valid welltest. " IO'-'LEY SURVEY INTERPRET-'TION Common Abbreviations L U. ,, Lower Up,e! U.U. ., Upper Ups~ u.B. ,= upper rn. B. =: mlddl~ lk~y I.B. - lower My' Corr. ,Scald. TABULATION SHEET: JOINTS: are numbered from the top down. Numbering starts with the first full joint below the Christmas tree. PUP JOINTS: are designated by decimal 'numbers. For example, joint 32.1 represents the first pup joint below joint no. 32. SPECIAL TOOLS & NIPPLES: are designated by letters. For example, "B" is the second spedal tool or nipple from the top of the well. ..GAS LIFT. MANDRELS: are numbered down from the top, as shown: GLM (1), GLM (2), etc. , TABIILATION SYMBOLS We use a circle as the basic tabulation symbol. The Kinley Caliper records the simultaneous action of all fifteen or thirty feelers. Our survey, therefore, has either 15 or 30 lines. These lines provide a view around the'circumference of the inner surface of the pipe. A complete circle on the tabulation sheet indicates that at least 14 of 15 feelers, or 28 of 30 feelers found tubing wall reductiotxs at the same depth in the well. This would be described as a ring. The number of feelers that indicate tubing wall reductions at the same depth is also noted on the tabulation sheet. For a 15-Feeler Caliper D3to5 D6to9 D 10to 13 D 14 tol5 [~] 6to 11 PIT- For a 30-Feeler Caliper D 12 to 19 D 20 to 27 D 28 to 30 MEAStlREMENT SYMBOLS A number alone represents the depth of penetration, expressed in hundredths of an inch, of the deepest pit. In this example 0.08". A groove around the pipe, found by 14 of 15 feelers or 28 of 30 feelers. The number inside the circle represents the maximum depth of the ring, expressed in hundredths of an inch. A PARTIAL RING - A groove around the pipe, found by 3 to 13 of 15 feelers or 6 to 27 of 30 feelers. The number inside the partial drcle represents the maximum depth of the ring, expressed in hundredths of an inch. MINOR DAMAGE - Indicates a "minor" amount of damage that is not severe enough to warrant measurement. NO COMMENT - Indicates no damage was found in that joint. Arco (Alaska), Inc. Prudhoe Bay, AK Drill Site #12-32 June 30, 1994 Survey No. 23991T-30 Chart No. X1507 This is the first survey of this well to be made with the Kinley 30- Feeler Microscopic Caliper. The condition of the internal surface of the ~ ~1/2" 17# Buttress tubing in the well, from 0' to ~2,420' (WLM), is covered in this report. The deepest penetration recorded in the survey is in a line of corrosion located in Joint #295. This penetration measures 0.22" or 72% of the tubing wall thickness. A cross-sectional drawing and a photocopy of the recordings for Joint #295, at the location of the penetration, are included in this report. The condition of the tubing surveyed and analyzed ranges from good to poor with respect to corrosive damage. Indications of damage are recorded in all of the joints in the forms of scattered pits, lines of pits, areas of corrosion, lines of corrosion, and roughness of the tubing I.D. As illustrated in the Corrosion Profile, the deepest penetrations are recorded in the lower portion of the tubing interval surveyed. Indications of corrosive damage are recorded in the pup joints and flow couplings associated with the GLM's and other tool assemblies. The deepest penetration recorded in these areas is in an area of corrosion located in the lower pup joint (Joint' #303.2) of GLM (8). This penetration measures 0.18" or 59% of the tubing wall thickness. Photocopies of the traces for GLM (8) and other representative tool assemblies are included in this report. As indicated in the Tabulation Sheets, an almost continuous line of corrosion is recorded throughout the tubing interval surveyed and analyzed. Much of the corrosive damage that is recorded is widespread with respect to circumferential wall loss. Many joints have recordings of a line of corrosion measuring deeper than the general areas of corrosion recorded in the joints. As a result, the nominal I.D. is unknown and the penetration values given may be slightly different than the actual wall loss. One of the caliper feelers did not function properly from Joint #1 to Joint #88. The rest of the survey recorded with the remaining 29 feelers was not affected by this malfunction. CALIPER TECHNICIAN Ken Bullock SURVEY ANALYST Mark A. Brown ARCO (ALASKA), INC. Continued Prudhoe Bay, AK Drill Site #12-32 Page 2 Survey #23991 mab Distribution: ARCO (ALASKA), INC., ATTENTION': Records Processor, Room ~AT0-1529, P. O. Box 10-3240, Anchorage, AK 99510-3240 (TR) ARCO (ALASKA), INC., ATTENTION: Mr. Jason Weaver, Room #AT0-1788, P. O. Box 10-3240, Anchorage, AK 99510-3240 (1R) Chart received: Report mailed: 07-05-94 07-21-94 KINt EY CALIPER TALL Y, HEET (Composite) DRILL SITE 12 #32 Survey # 23991 June 30, 1994 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Penetrations Over 85% '(Possible Hole) # of Jts Penetrations 41 - 85% (Poor) JT. #'s 290.1 301.1 303.2 273 281 282 283 286 292 293 294 295 302 303 304 305 Penetrations 21 - 40% JT. #'s 54.2 268.1 305.1 305.2 32 35 47 48 58 59 114 115 174 178 197 201 215 216 229 232 239 240 247 248 256 257 265 266 275 276 (FaiO 268.2 305.3 41 49 60 118 181 205 218 233 241 249 258 267 277 Penetrations 11 - 20% (Good) 279.1 8 42 50 61 120 184 206 220 234 242 250 259 268 284 274 278 279 280 287 289 290 291 297 298 300 301 279.2 11 43 51 64 123 185 207 221 235 243 252 260 269 285 290.2 301.2 303.1 25 26 27 44 45 46 55 56 57 67 74 113 146 165 173 ' 193 194 195 208 210 213 223 225 228 236 237 238 244 -245 246 253 254 255 262 263 264 270 271 272 288 296 299 28 120 172 Penetrations 1 - 10% (Very Good) 12 No Penetrations Recorded TOTAL JOINTS SURVEYED: 334 ( Includes 29 Pup Joints ) CO OSION DRILL S/TE 12 #32 PRUDNOE BAY. Al< June 30. 1994 SURVEY # 23991 5 1/2" 17# BUTTRESS CORROSIVE DAMA GE £REQUENC Y DISTRIBUTIONS MAXlMUM PENE7-RA TION NUMBER OF JOINTS CONFIGUt~ T/ON NUMBER OF JOINTS DESCRIPTION BODY PENETRATtONS % WALL LOSS 20 40 60 80 PIT DEPTH (I/~00 KINLEY PIT DEPTH R~A~K CHART ( MEAN STATISTICAL DISTRIBUTION OF DFFPEST BODY PENETRATION PER JOINT · DRILL SITE 12 #32 Survey# 2399~ PRUDHOE BA Y~ AK 5 ~/2" ~ 7~ BUTTRESS ~ne 30~ ~ 994 0.304'Wolt TMckness O, 30 0.24 0,22 0,']4 O, 12 O, ~0 ~00 % P~obobflfty Of ~ Hole 20 50 MAXIMUM PROBABLE PENFTRA TIO/~ DRILL SITE 12 #32 5 1/2" 17# BUTTRESS Survey #2399! O.D. = 5.500 In, LD. = 4.892 tn, 9 8 ~0 0.06 o. o9 7 0.06 0.04 0.02 12 5 008 0.04 13 4 O. 12 0.06 14 0.10 3 0.04 15 2 0.00 16 0.05 I O, 02 I7 O. 08 3O O. O0 18 0,16 29 0.05 19 &lO 20 27 O, 10 0,08 21 26 0.00 0.02 22 25 o. ~o 23 24 o. o3 0.08 0.06 28 0.07 Description: JL #287 · CORROSION LOWER BODY - a 16' = 53% Percent Area Reduction = 18, 77 % Tota/ Area Remaining = 4.03 Sq,/n, DRILL SITE 12 #32 Survey #23991 5 1/2" 17# BUTTRESS O,D, = 5,5001n. LD = 4.892 13 0.22 8 10 o. oo ooo 7 o, oo o, oo 0.00 0.00 12 5 0.00 0,00 4 0.00 I4 o. 18 3 0,00 1E 0.00 2 0~00 16 0.00 t o. oo 17 0.0o 3O O. O0 18 O, O0 29 O, 00 19 0.00 20 27 O. O0 O, O0 2I 26 0.00 0.00 22 25 0.00 23 24 0,00 0.00 0.00 28 O. O0 Description: JT, #295 .-LINE OF CORROSION-0.22"= 72% Percent Area Reduction = 3.22 % Total Area RemainZng = 480 SqJn~ JOINT NO KINLEY CA," PER 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chad # X1507 Feeler Ratio I · I JOINT TABULA '--gN SHEET DRILL SITE 12 #32 PRUDHOE BAY, AK Survey # 23991 June 30, 1994 Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY PENETRATION PENETRATION COMMENTS Corr. u.B.; Pup Jt. )Jt. 1st full length Jt. below Tree Line of shallow corr. u.B.; Pup Jt. Jt. Line of shallow corr.; Pup JL Shallow corr.. Shallow corr. COlT. Scatd. shallow pits Line of corr.; Shallow pit m.B. (.04") Line of corr.; Scatd. shallow pits (.04") Line of corr.; Shallow corr. (.03") Shallow con'. Line of corr.; Shallow corr. (.04") Line of corr.; Shallow corr. (.03") Shallow corr. Shallow corr. Corr. Corr. Lines of corr. Lines of corr. Lines of corr. Lines of corr. Lines of shallow corr. Lines of corr. Lines of corr. Lines of shallow corr. Lines of corr. Lines of con'. Lines of corr. Lines of shallow corr.; Shallow corr. u.B. (.03") Line of shallow corr.; Shallow corr. u.B. (.04") Lines of shallow corr. Lines of corr. Lines of corr. Lines of corr. Lines of corr. Lines Lines Lines of corr.; Shallow pits u.B. & I.B. (.04") of corr.; Shallow pit 1.B. (.04") of shallow corr. Lines of shallow corr. Lines of shallow corr. Lines of shallow coif. Lines of corr. Lines of shallow corr. Lines of corr. Lines of corr. Lines of corr. of corr. Lines of corr. Lines of corr. Corr. Lines of corr. DAMAGE PROFILE 0 (% WALL) lC -BODY m -UPSET KINLEY CA PER JOINT TABULAT N SHEET 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chad # X1507 Feeler Ratio I · 1 DRILL SITE 12 #32 PRUDHOE BAY, AK Survey # 23991 June 30, 1994 Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAeE JOINT PENETRATION PENETRATION A PROFILE NO % INCHES % INCHES COMMENTS "(% WALL) 51 26 0.08 Lines of corr.; Shallow corr. (.03") 52 20 0.06 Lines of corr.; Shallow corr. u.B. (.04") 53 20 0.06 Lines of corr.; Shallow corr. 1.B. (.02") 54 20 0.06 Lines of corr.; Shallow pit I.B. (.05") 54.1 13 0.04 Lines of shallow corr.; Pup Jt. 54.2 23 0.07 Lines of corr.; How Coupling; "SSSV" Nipple Assembly (A) '. 54.3 13 0.04 Shallow pit I.B.; Flow Coupling 54.4 16 0.05 Line of shallow corr.; Pup Jt. 54.5 13 0.04 Shallow pits m.B.; Pup Jr. 55 33 0.10 Lines of corr. ,' 56 26 0.08 Lines of corr. 57 33 0.10 Lines of corr.; Pit u.B. (.06") 58 26 0.08 Lines of corr. 59 26 0.08 Lines of corr. 60 26 0.08 !Lines of corr. 61 26 0.08 Lines of corr. 62 20 0.06 Line of corr. 63 20 0.06 Line of corr. 64 23 0.07 Line of corr.; Pits u.B. (.06") 65 20 0.06 Line of corr. 66 20 0.06 Line of pits 67 26 0.08 Line of corr. 68 20 0.06 Line of corr. 69 20 0.06 Line of corr. 70 13 0.04 Line of shallow corr. 71 20 0.06 Line of corr. 72 20 0.06 Line of corr. 73 20 0.06 Line of corr. 74 23 0.07 Line of corr. 75 16 0.05 Line of shallow corr. 76 20 0.06 Line of corr. 77 16 0.05 Line of shallow corr. 78 20 0.06 Line of corr. 79 13 0.04 Line of shallow corr. 80 20 0.06 Line of corr. 81 20 0.06 Line of corr.; Pit u.B. (.06") 82 20 0.06 Line of corr. 83 16 0.05 Line of shallow corr. 84 13 0.04 Shallow corr. 85 20 0.06 Line of corr.; Roughness (.01") 86 13 0.04 Shallow corr. 87 10 0.03 Shallow corr. 88 13 0.04 Shallow corr. 88.1 13 0.04 Shallow corr.; Pup Jt.; GLM (1) 88.2 7 0.02 Shallow corr.; Pup Jt. 89 20 0.06 Corr. 90 13 0.04 Shallow corr. 91 16 0.05 Shallow corr. 92 7 0.02 Shallow corr. 93 20 0.06 Line of corr. 94 13 0.04 Line of shallow corr. 95 10 0.03 Shallow corr. 96 7 0.02 Line of shallow corr. 97 16 0.05 Line of shallow corr.; Shallow corr. (.02") 98 20 0.06 Line of corr.; Shallow corr. (.02") 99 16 0.05 Line of shallow corr.; Shallow corr. (.02") 100 20 0.06 Line of corr.; Shallow corr. (.02") - BODY I - UPSET KINLEY CA' PER JOINT TABULA gN SHEET 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chart# X1507 Feeler Ratio I · I DRILL SITE 12 #32 PRUDHOE BAY, AK Survey # 23991 June 30, 1994 Run # 1 MAXIMUM MAXIMUM BODY DAMAGE PENETRATION PENETRATION PROFILE JONiNoT UPSET/MAKEUP % INCHES % INCHESCOMMENTS o (% WALL)" 101 16 0.05 Line of shallow corr.; Shallow corr. (.04") 102 20 0.06 Line of corr.; Pit m.B. (.06") 103 20 0.06 Line of corr.; Shallow corr. (.05") 104 20 0.06 Line of corr. 105 20 0.06 Line of corr.; Pit 1.B. (.06") 106 20 0.06 ~ Line of corr. 107 20 0.06 Line of corr. 108 ,, 20 0.06 Line of corr.; Shallow pit 1.B. (.04") 109 20 0.06 Line of corr. 110 20 0.06 Line of corr. 111 20 0.06 Line of corr. 112 20 0.06 Line of corr. 113 23 0.07 Line of corr. 114 23 0.07 Line of corr. 115 23 0.07 Line of corr. 116 20 0.06 Line of corr. 117 20 0.06 Line of corr. 118 23 0.07 Line of corr. 119 20 0.06 Line of corr. 120 23 0.07 Line of corr. 121 20 0.06 Line of corr. 122 20 0.06 Line of corr.; Pit u.B. (.06") 123 23 0.07 Line of corr. 124 20 0.06 Line of corr. 125 20 0.06 Line of corr. 126 20 0.06 Line of corr. 127 20 0.06 Line of corr. 128 20 0.06 Line of corr.; Shallow pit 1.B. (.04") 129 13 0.04 Line of shallow corr.; Shallow pit 1.B. (.03") 130 20 0.06 Line of corr. 131 16 0.05 Line of shallow corr. 132 16 0.05 Line of shallow corr. ' 133 10 0.03 Line of shallow corr. 134 20 0.06 Line of corr. 135 20 0.06 Line of corr. 136 20 0.06 Line of corr. 137 20 0.06 Line of corr. 138 13 0.04 Line of shallow corr. 139 20 0.06 Line of corr. 140 20 0.06 Line of corr. 141 20 0.06 Line of corr.; Shallow pit m.B. (.04") 142 20 0.06 Line of corr.; Shallow pit u.B. (.03") 143 20 0.06 Line of Corr. 144 20 0.06 Line of corr. 145 16 0.05 Line of shallow corr. 146 23 0.07 Line of corr. 147 10 0.03 Line of shallow corr. 148 10 0.03 Line of shallow corr. 149 20 0.06 Line of corr. !50 20 0.06 Line of corr.; Shallow pit m.B. (.03") ~J~-BODY I -UPSET Caliper Specialists Since 1953 KINLEY CORPORATION 5815 Royalton, Houston, Texas 77081-2993 U.S.A. Phone (71 3) 664-4501 Telefax (71 ;3) 664-1 037 SERVICE AVAILABLE WORLDWIDE WITH ALL KINLEY WIRELINE TOOLS Calipers · Tubing Perforators · Sand Line Cutters · Power Jars · Measuring Line Cutters ° · o $ · ...... . 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KINLEY CA ' PER JOINT TAB ULA gN SHEET 5 1./2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chad # X1507 Feeler Ratio 1 ' 1 DRILL SITE 12 #32 PRUDHOE BAY, AK Survey # 23991 June 30, 1994 Run # 1 MAXIMUM MAXIMUM !UPSET/MAKEUP BODY DAMAOE JOINT PENETRATION PENETRATION n PROFILE NO % INCHES % INCHES COMMENTS "(% WALL) 151 20 0.06 Line of corr.; Shallow corr. (.03") 152 20 0.06 Line of corr. 153 20 0.06 Line of corr.; Shallow corr. (.03") 154 16 0.05 Line of shallow corr. 155 20 0.06 Line of corr.; Shallow pits m.B. & 1.B. (.04") 156 16 0.05 Line of shallow corr.; Shallow pit I.B. (.04") 157 20 0.06 Line of corr.; Shallow c°rr. (.02") 158 20 0.06 Line of corr.; Shallow corr. (.02") 159 16 0.05 Line of shallow corr. 160 16 0.05 Line of shallow corr.; Shallow corr. u.B. (.02") 161 20 0.06 Line of corr. 162 13 0.04 Line of shallow corr. 163 20 0.06 Line of corr.; Pit I.B. (.06") 164 20 0.06 Line of corr.; Shallow pit u.B. (.03") 165 23 0.07 Line of corr. 166 20 0.06 Line of corr.; Shallow pits 1.B. (.04") 167 20 0.06 Line of corr. 168 20 0.06 Line of corr. 169 20 0.06 Line of corr. 170 20 ~ 0.06 Line of corr. 171 20 0.06 Line of corr. 172 20 0.06 Line of corr. 173 23 0.07 Line of corr. 174 23 0.07 Line of corr. 175 20 0.06 Line of corr. 176 16 0.05 Line of shallow corr, 177 16 0.05 Line of shallow corr.; Shallow corr. I.B. (.04") 177.1 13 0.04 Line of shallow corr.; Pup Jt.; GLM (2) 177.2 13 0.04 Line of shallow corr.; Pup Jt. 178 23 0.07 Line of corr.; Shallow corr. (.04") 179 20 0.06 Line of corr.; Shallow corr. (.04") 180 20 0.06 Line of corr.; Shallow corr. (.04") 181 23 0.07 Line of corr.; Shallow corr. (.03") 182 16 0.05 Line of shallow corr.; Shallow corr. (.02") 183 20 0.06 Line of corr.; Shallow corr. (.02") 184 26 0.08 Line of corr. 185 26 0.08 Line of corr. 186 20 0.06 Line of corr. ...187 20 0.06 Line of corr.; Shallow pits u.B. & m.B. (.03") 188 20 0.06 Line of corr. 189 20 0.06 Line of corr. 190 20 0.06 Line of corr.; Shallow pits I.B. (.04") 191 20 0.06 Line of corr. 192 20 0.06 Line of corr. .... ,193 26 0.08 Line of corr. 194 26 0.08 Line of corr.; Shallow corr. I.B. (.04") 195 26 0.08 Line of corr. 196 20 0.06 i Line of corr. 197 39 0.12 Pit I.B.; Line of corr. (.07") I o 198 20 0.06 Line of corr. 199 20 0.06 Line of corr.; Shallow corr. u.B. (.02") 200 20 0.06 Line of corr. -BODY I -UPSET KINLEY CA PER JOINT TABULAT 'gN SHEET 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chad # X1507 Feeler Ratio 1 · I DRILL SITE 12 #32 PRUDHOE BAY, AK Survey # 23991 June 30, 1994 Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETRATION PENETRATION n PROFILE 1( NO % INCHES % INCHES COMMENTS WALL) 201 23 0.07 Line of corr. 202 7 0.02 Line of shallow corr. 203 20 0.06 Line of corr. 204 20 0.06 Line of corr. 205 23 0.07 Line of corr. 206 33 0.10 Line of corr. 207 26 0.08 Line of corr. 208 23 0.07 Pits u.B.; Line of shallow corr. (.03") 209 20 0.06 Line of corr. 210 26 0.08 Line of corr. 211 20 0.06 Line of corr. 212 20 0.06 Line of corr. 213 23 0.07 Line of corr. 214 20 0.06 Line of corr. 215 33 0.10 Line of corr. 216 26 0.08 Line of corr. 217 20 0.06 Line of corr. 218 26 0.08 Line of corr.; Shallow corr. m.B. (.02") 219 20 0.06 Line of corr. 220 23 0.07 Line of corr. 221 33 0.10 Line of corr. 222 20. 0.06 Line of corr. 223 26 0.08 Line of corr. 224 20 0.06 Line of corr. 225 26 0.08 Line of corr. 226 20 0.06 Line of corr. 227 20 0.06 Line of corr. 228 26 0.08 i Line of corr. 229 33 0.10 1 Line of corr. 230 20 0.06 Line of corr. 231 20 0.06 Line of corr. 232 33 0.10 Line of corr.; Shallow corr. u.B. (.03") 233 36 0.11 Line of corr. 234 26 0.08 Line of corr. 235 26 0.08 Line of corr. 236 26 0.08 Line of corr.; Shallow corr. u.B. (.03") 237 26 0.08 Line of corr.; Shallow pit u.B. (.04") 238 26 0.08 Line of corr.; Shallow pit u.B. (.04") 239 26 0.08 Line of corr.; Line of shallow pits 1.B. (.04") 240 36 0.11 Line of corr. 241 23 0.07 Line of corr.; Line of pits m.B. (.06") 241.1 20 0.06 Line of corr.; Pup Jt.; GLM (3) 241.2 10 0.03 Line of shallow corr.; Pup Jt. 242 26 0.08 Line of corr.; Shallow corr. (.04") 243 26 0.08 Line of corr. 244 26 0.08 Line of corr. 245 26 0.08 Line of corr.; Shallow corr. (.02") 246 26 0.08 Line of corr. 247 26 0.08 Line of corr.; Shallow corr. u.B. & m.B. (.04") 248 33 0.10 Line of corr.; Shallow corr. u.B. (.03") 249 30 0.09 Corr. 250 26 0.08 Corr. -BODY I -UPSET KINLEY CA '- PER JOINT TABULA N SHEET 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chart # X1507 Feeler Ratio 1 · I DRILL SITE 12 #32 PRUDHOE BAY, AK Survey # 23991 June 30, 1994 Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETRATION PENETRATION n PROFILE NO % INCHES % INCHES COMMENTS "(% WALL) 251 20 0.06 Line of corr.; Shallow pit I.B. (.02") 252 26 0.08 Line of corr. 253 26 0.08 Corr. 254 26 0.08 Line of corr.; Shallow pit m.B. (.02") 255 26 0.08 Line of corr.; Shallow pit I.B. (.04") 256 33 0.10 Corr. 257 33 0.10 Line of corr.; Shallow pit u.B. (.02") 258 33 0.10 Line of corr.; Shallow corr. 1.B. (.04") 259 26 0.08 Corr. 260 33 0.10 Line of corr. 261 13 0.04 Shallow corr. 262 33 0.10 Line of corr.; Shallow corr. (.05") 263 33 0.10 Line of corr. 264 26 0.08 Line of corr.; Pit 1.B. (.06") 265 26 0.08 Line of corr. 266 33 0.10 Line of corr. 267 33 0.10 Line of corr. 268 33 0.10 Corr. 268.1 26 0.08 Line of corr.; PupJt.; GLM (4) 268.2 33 0.10 Line of corr.; Pup Jt. 269 39 0.12 Line of corr.; Shallow corr. I.B. (.04") 270 33 0.10 Corr. 271 26 0.08 Line of corr.; Shallow corr. u.B. (.02") 272 33 0.10 Line of corr. 273 46 0.14 Line of corr.; Shallow pits u.B. & I.B. (.04") 274 53 0.16 Line of corr.; Shallow pit m.B. (.04") 275 26 0.08 Line of corr.; Shallow corr. u.B. (.02") 276 39 0.12 Line of corr. 277 36 0.11 Line of corr.; Shallow pits u.B. & 1.B. (.04") 278 46 0.14 Line of corr.; Corr. (.08") 279 43 0.13 Line of corr.; Shallow corr. (.04") 279.1 33 0.10 Line of corr.; Pup Jt.; GLM (5) 279.2 39 0.12 Line of corr.; Pup Jt. 280 46 0.14 Line of corr.; Shallow corr. (.05',') 281 43 0.13 Line of corr.; Shallow pit I.B. (.04") 282 53 0.16 Line of corr.; Corr. (.08") 283 59 0.18 Line of corr.; Corr. (. 12") 284 33 0.10 Line of corr. 286 43 0.13 Line of corr. 287 53 0.16 Corr. 288 39 0.12 Line of corr.; Pit u.B. (.09") 289 53 0.16 Line of corr.; Shallow pit m.B. (.03") 290 53 0.16 Line of corr.; Shallow pit I.B. (.04") 290.11 46 0.14 Line of corr.; Pup Jt.; GLM (6) 290.2i 33 0.10 Corr.; Pup Jt. 291 49 0.15 Line of corr.; Partial ring 1.B. (. 14") ,292 66 0.20 Line of corr. 294 59 0.18 Line of corr.; Scatd. pits (.08") 295 72 0.22 Line of corr. 296 39 0.12 Line of corr. 297 66 0.20 Line of corr.; Line of pits (.15") 298 66 0.20 Line of corr.; Pits I.B. (.12") 299 39 0.12 Line of corr.; Shallow pit m.B. (.04") lll/ 300 46 0.14 Line of corr.; Corr. 1.B. (.10") -BODY I -UPSET JOINT NO .... ] 301 13o1.1 13Ol.2 13o2 1303 1 303.1 1 303.2 13o5.1 1 305.2 JOINT TABULA/ ' 'iN 3lila'E 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chart # X1507 Feeler Ratio 1 · I DRILL SITE 12 #32 PRUDHOE BAY, AK Survey # 23991 June 30, 1994 Run # 1 MAXIMUM UPSET/MAKEUP PENETRATION .., °/o INCHES MAXIMUM BODY PENETRATION % I INCHES 46I 0.14 43I 0.13 36I 0.11 46[ 0.14 63I 0.19 39I 0.12 59I o. 18 46I 0.14 43I 0.13 39I 0.12 39[ 0.12 39I 0.12 COMMENTS Line of corr.; Shallow pits u.B. (.04") Line of corr.; Pup Jt.; GLM (7) Corr.; Pup Jr. Line of corr. Line of corr.; Corr. I.B. (.10"); Pits u.B. & m.B. (.06") Line of corr.; Pup Jt.; GLM (8) Corr.; Pup Jt. Line of corr.; Line of pits u.B. (.08") Line of corr.; Pits m.B. (.07") Line of corr.; Pup Jt. Packer Assembly (B); (Line of corr.; Pit I.B. in Packer.Assembly) Corr.; Pup Jt. Survey ends in Jt. #305 @ 12,420' (WLM) DAMAOE (% WAPROFILE LL) 100 ~ -BODY I -UPSET ......................... ~/-~ Id · ................ ,..-'__.--: ................. u j-i'h~, ' .~,_-~ ':. .IJ ,~,~. · I. IL W · . ,o i' "'" ' " ' ' : ' ' "' - ' ': ' "'"'~ '"*'~'""'""-~'-' ' ' ''!' ' ':' ' ' '"-" - ' :,.._.._L ... Il ,. _.". :'_ .."'-___-it=-.. .=.-":'"'""'":'"'"--'-"'F-' .......... :::"-~-'-'-'"'"-:,'=~?d:'-:': ......................... ':-.','-,'==:-: ...... ::'-:--'-'-? ...... ::'--:'-~':'"':-=';-~-?-~ L.:-.:/..=....:;:: ~:_.:L:.,,=...:...=:..:..:~J:.=.::.=L: =;.;,...~: .:_= ~ ::.: ~. ." ' "" :'"~7 . · :' "i · ".:: ........... . -'?-=: ......... .- '":" ~'" _-----'=:---' ."F-'x,~ .=,T..-~'-T,~,.r : '~'" -' ' 'i - ..' F .... '. i ... ""- · ..-.-._;:..__-=-- _;: ....... .....-::..':.: __~,_ ~ .... -._-- :-.-, ,-~ '~.. -...:. -I__~-. ..L · '" -"'(" ' ' ! ' '.'.: : "" -'-" .':4 · ' .' ~-q_..~.~..= .~r :. =. - ' : : ' " · o · ...... :.,'_:..'.. _.. 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',..:' ' ' -. · "~' ':-"" : -:': ...... ~_ ..... .:. ..... :: -...,,::: .' !', , :,,,,.:: :-::'-- ':~,' :il" --~_" _ j~ L~ncs oF co.os,on ~l STATE OF ALASKA ALASK,a; L AND GAS CONSERVATION C( VIISSION REPORT UF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown -- Stimulate -- Plugging Perforate X Pull tubing Alter casing Repair well 2. Name of Operator 5. Type of Well Other ?/~ F~' 6. Datum of elevation(DF or KB) ,~, ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 9951O-O36O Development Exploratory Stratigraphic 4. Location of well at surface 1030' FSL, 125' FEL, Sec. 17, T10N, R15E, UM At top of productive interval 741' FNL, 2305' FEL, Sec. 16, T10N, R15E, UM At effective depth 653' FNL, 1956' FEL, Sec. 16, T10N, R15E, UM At total depth 645' FNL, 1924' FEL, Sec. 16, T10N, R15E, UM 12. Present well condition summary Total depth: RE(EJVED FEB ~ 2_ 199;~ AJaska 0il & Gas Cons. C0mmiss[o~ Anc. hora_~a . measured 13500 feet Plugs(measured) None 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-32 9. Permit number/approval number 10. APl number 50 - 029 - 21910 11. Field/Pool Prudhoe Bay Oil Pool true vertical Effective depth: measured true vertical Casing Length Conductor 80' Sudace 4400' Intermediate 12762' 9-5/8" Liner 1019' 7" 9222 feet 13455 feet 9191 feet Junk(measured) None Size Cemented Measured depth True vertical depth 20" 2150 # Poleset 110' 110' 13-3/8" 2500 sx CS III & 600 sx Cl 'C' 4434' 3554' Top job w/120 sx CS II 500 sx Cl 'G' 12793' 8708' 350 sx Cl 'G' 13499' 9221' Perforation depth: measured 12930-12948'; 12960-12980';12992-13033'; 13037-13072'; 13076-13111'; 13116-13126'; 13130-13140'; true vertical 8734-8747'; 8756-8771'; 8779-8810'; 8812-8838'; 8841-8867'; 8871-8878'; 8881-8888' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 12442' MD; 4-1/2", 12.6#, L-80, PCT tail @ 12540' MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2221' MD; Baker -1 packer @ 12423' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 663 452 5683 -- Subsequent to operation 757 ji 982 5620 -- Tubing Pressure 329 330 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil,,,,X Gas Suspended Service .Signed ~ (~ ~Title-_~, Form 10-404 Rev 06/15/88 ~ cc: S. Wallace/DS Engr/J. W. Peirce 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Senior Engineer Date Z.//~,/~$ SUBMIT IN DUPLICATEh Daily Report of Operations DS12-32 12/26/92 MIRU HIS. PT. RIH w/GUN #1. Shoot 12960-12980' MD. POOH. LD GUN # 1. All shots fired. Release well. FEB ~ 2 t99~ Alaska Oil & Gas Cons. Anchorage ~ I A I !- ~1- AI_ASKA ~ r~ ALASK,;~*'~IL AND GAS CONSERVATION C~MISSI~ ~ REPOR3 JF SUNDRY WELL OF_RATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging ~ Perforate X Pull tubing ,.,..- Alter casing ~ Repair well 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1030' FSL, 125' FEL, Sec. 17, T10N, R15E, UM At top of productive interval 741' FNL, 2305' FEL, Sec. 16, T10N, R15E, UM At effective depth 653' FNL, 1956' FEL, Sec. 16, T10N, R15E, UM At total depth 645' FNL, 1924' FEL, Sec. 16, T10N, R15E, UM 5. Type of Well Development X Exploratory Stratigraphic Other 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-32 9. Permit number/approval number 89-11 10. APl number 50 - 029-21910 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 13500 feet true vertical 9222 feet Effective depth: measured 13455 feet true vertical 9191 feet Casing Length Size Conductor 80' 20" Sudace 4400' 13-3/8" Intermediate 12762' Line r 1019' Plugs(measured) None Junk(measured) None Cemented Measured depth 2150 # Poleset 110° 2500 sx CS III & 600 sx CI 'C' 4434' Top job w/120 sx CS II 9-5/8" 500 sx Cl 'G' 12793' 7" 350 sx CI 'G' 13499' True vertical depth 110' 3554' 8708' 9221' Perforation depth: measured 12930-12948; 12992-13033'; 13037-13072'; 13076-13111'; 13116-13126'; 13130-13140' true vertical 8734-8748'; 8853-8883'; 8886-8912'; 8915-8941 '; 8945-8952'; 8955-8962' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 12442' MD; 4-1/2", 12.6~t, L-80, PCT tail @ 12540' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2221' MD; Baker FB-1 packer @ 12423' MD 13. Stimulation or cement squeeze summary .~ ~L'E ~ V ~D 14. Intervals treated(measured) APR - S92 Treatment description including volumes used and final pressure Reoresentative Daily Averaoe Production or Iniection Data Al]ch0rage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1781 3130 4435 -- 271 Subsequent to operation 2179 3711 5419 -- 282 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X..~_ Gas_._ Suspended...._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned //~~'~ ~--~ ~~'~--~/'~-"-- Title Form 10-404 Rev 06/15/88 SW/JWP/DS Engr. SUBMIT IN DUPLICATE Well 12-32 Well Operations Summary 2/13/91 MIRU. PT BOPS to 2500#. PT lubricator to 2500#. RIH w/18' gun. Perforate 12930-12948. POOH. RD. Return well to production. (All depths reference BHCS 03/12/89.) RECEIVE'D Alaska Oil & Gas Cons. CoI~mission AnChorage ~-. STATE OF ALASKA --" ALASKA ~AND GAS CONSERVATION CC .vllSSION0 ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Puli tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1030' FSL, 125' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 741' FNL, 2305' FEL, Sec. 16, T10N, R15E, UM At effective depth 653' FNL, 1956' FEL, Sec. 16, T10N, R15E, UM At total depth 645' FNL, 1924' FEL, Sec. 16, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service X RECEIVED F~!B I 9 ,,,,, Alaska 0il & Gas 00ns. 60r~'tssi0g Anchorage 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-32 9. Permit number/approval number 89-11 10. APl number 50 - 029-21910 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13500 feet true vertical 9222 feet Effective depth: measured 13455 feet true vertical 9191 feet Casing Length Size Conductor 80' 20" Su dace 4400' 13-3/8" Production 12762' 9-5/8" Liner 1019' 7" Plugs(measured) Junk(measured) Cemented Measured depth True vertical depth 2150# Poleset 110' 110' 2500 sx CS III & 600 sx CI 'G' 4434' 3554' Top job w/120 sx CS II 500 sx CI 'G' 12793' 8708' 350 sx CI 'G' 13499' 9221' Perforation depth: measured 12992-13033'; 13037-13072'; 13076-13111'; 13116-13126'; 13130-13140' true vertical 8853-8883'; 8886-8912'; 8915-8941'; 8945-8952'; 8955-8962' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 12442' MD; 4-1/2", 12.6~, L-80, PCT tail @ 12540' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2221' MD; Baker FB-1 packer @ 12423' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached T~eatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 761 482 1313 1708 3126 4433 Tubing Pressure 209 296 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas_._ Suspended Service. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 617 DRR c: J. Gruber, ATO-1478 SUBMIT IN DUPLICATE~ DS 12-32 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF ZONE 4 8/1/90: MIRU & PT equipment to 7500 psi. perforations at: 12992 - 13033' MD (Z4) 13037 - 13072' MD (Z4) 13076 - 13111' MD (Z4) 13116 - 13126' MD (Z4) 13130 - 13140' MD (Z4) Pumped a Propped Fracture treatment through Ref. Log' BHCS 3/12/89. Pumped: a) 311 bbls 50# Uncrosslinked Pre Pad, @ 45 bpm, b) Shutdown. ISIP @800. followed by Resumed pumping: c) 2800 bbls Crosslinked Pad, @ 45 - 55 bpm, followed by d) 1200 bbls Slurry w/proppant concentrations of 2 to 10 ppg, followed by e) 156 bbls Flush, @ 55 bpm. Placed a total of 147,000 lbs of proppant into the formation. Rigged down. 8/3/90 - 11/10/90' Performed multiple proppant fill cleanouts. Flowed well intermittently. 12/8/90- Performed a scale inhibition treatment. Returned well to full time production and obtained a valid production test. & Gas Cons. Commissio~ Anchorage 1. Type of Request: STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION ~MMISSION APPLICATION FOR SUNDRY APPROVAL Abandon Suspend Operation shutdown Re-enter suspended well Variance 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1030' FSL, 125' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 741' FNL, 2305' FEL, Sec. 16, T10N, R15E, UM At effective depth 653' FNL, 1956' FEL, Sec. 16, T10N, R15E, UM At total depth 645' FNL, 1924' FEL, Sec. 16, T10N, R15E, UM 12. Present well condition summary Total depth: measured 13500 feet Plugs(measured) true vertical 9222 feet 1 1.990 Effective depth: measured 13455 feet true vertical 9191 feet Junk(measured) ~ OJ~ & ~as Co[tS, ~~gQ Casing Length Size Cemented Measured depth True vertical depth 80' 20" 2150# Poleset 110' 110' Sudace 4400' 13-3/8" 2500 sx CS III & 600 sx CI 'G' 4434' 3554' Top job w/120 sx CS II 500 sx Cl 'G' 350 sx Cl 'G' Production 12762' 9-5/8" 12793' 8708' Liner 1019' 7" 13499' 9221' Alter casing Repair well Change approved program Pull tubing 2. Name of Operator ARCO Alaska, Inc. Time extension Stimulate X Perforate Other 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-32 9. Permit number 89-11 10. APl number 50 - 029-21910 11. Field/Pool Perforation depth: measured 12992-13033'; 13037-13072'; 13076-13111'; 13116-13126'; 13130-13140' true vertical 8853-8883'; 8886-8912'; 8915-8941'; 8945-8952'; 8955-8962' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 12442' MD; 4-1/2", 12.6~, L-80, PCT @ 12540' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2221' MD; Baker FB-1 packer @ 12423' MD 13. Attachments 14. Estimated date for commencing operation July 1990 16. If proposal was verbally approved Oil X Name of apl)rover Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer FOR COMMISSION U.~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance ~..~ £j Mechanical Integrity Test Subsequent form'required 10- Description summary of proposal X Detailed operations program BOP sketch X 15. Status of well classification as: Gas Suspended Date Approval Ng~ ~-, ,,.~...-,~ 7 Approved by order of the Commissioner ORIGINAL SIGNED-BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 381 DRR cc: J. Gruber, ATO-1478 P1(12-32)W1-3 Commissioner Date Approved Copy SUBMIT IN TRIPLICATE Returned Plugging Drill Site 12-32 Zone 4 Hydraulic Fracture Treatment PRELIMINARY PROCEDURE Arco Alaska intends to pump a hydraulic fracture treatment on well 12-32 as outlined below: · · · 1 · Si Pull gas lift valves and replace with dummy valves· Pressure test tubing / casing annulus. Rig up fracturing service company· Pump propped fracture treatment at 45 BPM using a cross linked water system with approximately 200,000 lbs of 16-20 proppant. The interval to be fracture stimulated is Zone 4 from 12,992 to 13,140'. The pump schedule is outlined as follows: A. B. C. D. E. F. G 2700 Bbl cross linked water pad 125 Bbl 2 PPG proppant 135 Bbl 4 PPG " 145 Bbl 6 PPG " 156Bbl 8PPG " 166 Bbl 10 PPG " 176 Bbl 12 PPG " If necessary rig up CTU and cleanout to PBTD. Install gas lift valves. Open well to flow gradually increasing the drawdown to allow proper fracture healing. C'O~LE'D TUBI. NG UNlIT BOP EGU ! PMENT 1. 5000 PSI ?" W£LLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYD~L~ SLIPS 4. 5000 PSI ,ii1/6" SHEAR RAM5 5. 5000 PSI 4 1/6" BLIND RAJAS 6. 5000 PSI 4 1/16" STUFFING BOX H]RELINE BOP EOUIPHENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRE:LINE RAUS (VARIABLE SIZE) · 1.5000 PSI 4 1/6" LUI~RICATOR 4. 5000 PSI 4 1/6'* FLOW TUBE PACK-OFF ARCO ALASKA, INC. F'~O. BOX i0036~ ANCHORAGE, ALASKA 995i0 DATE' t~-??-89~ _ REFERENCE' ARCO CASED HOLE FINALS 4-6 t ~--i 4-89 COLLAR/F'ERF RUN 5-i8 ~2-&-89 COLLAR RUN t, 5' ~-t~ ~--~8-8~ PERF RECORD RUN i2-.~2 i2-3-89 · F'RODUCTION PROFILE RUN t3-77~, t~.'~-i7-89 COLLAR RUN i, _,~'" t3-29 t2-tt-89 LEAl< DE'FECTION RUN i, 5" t4-i7 t2-t0-89 LEAK DETECTION RUN t, t 4-28 t 2-t 7-89 TUBING CUT'I-ER RECORD , ~ ~ m ' RUN t , 5" t7-3 t2-9-89 LEAK DETECTION RUN t, 5" i8-i4 12-8-89 F'ERF RECORD RUN~ i&2, F'LEA3E SIGN AND RETURN THE ATTAC~ED COPY AS RECEIF'T OF' DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFF'ECKER AlU-i~9~ .RECEIVED 9 ! DEC28198"~'~,'AN~'~ ~9 ..._- Alas~ Oil & Gas Con~ ~o.m~l~' ~chomge DISTRIBUTION ~ CENTRAL FILES ~ CHEVRON D & M ~ EXTENSION EXPLORATION ~, EXXON MARATHON ' MOBIL · · PHILLIPS F'B WELL FILES R & D BPX ~'TAT'E OF ALASKA TEXACO A'T'LA~~ C A M C O SCH CAME)[] ATLA£' C A M C O CAMCO C A M C [] C I--t 5013 W. Infemafional Airporf Road Anchorage, AK 99618-1199 ATTN: 5herrie NO. 8872 Company: Alaska Oii & Gas Cons Comm , Attn: Larry Grant i 3001 Porcupine Drive Anchorage, AK 99501 8/19/94 Field: Prudhoe Bay Well Log De~cripflon BL RR Sepia RF Sepia Mylar ?../~_~~,~" .I~S~-1-24A '" .... JpERF RECORD (7-29-94) ....... ... 1 .. 1 D.$. 3-16 ..... PERF RECORD (7-29-94) ... 1 1 ~ D-~S. 3-16 . INJEC PROFILE (7-30-94) ... 1 1 -- D.S. 12-17 PROD PROFILE (7-28-94) ...... 1 1 , , ~-D.S. 15.35 ....... PERF RECORD (7-31.94) ., 1 1 .... D.$. 17-4 PROD PROFILE (7-29-94), 1 1 ~-D.S. 1-30 ' ' PERF RECORD (7-29-94) 1'" 1 ----D:S. 12-2 PERF RECORD (7-30-94) .... 1 1 -----D.S. 12-32 PROD PROFILE (7-28-94) .... ~D~. 15-36 .... GR-C~L JEWELRY (7-31-94) ' ' ~)m.~ 15-36 PERF RE(X)RD (7-31-94) ............. ~ D~S~. 16-9A HIGH RATE INJEC PROFILE (7-31-94) , 'T'? '; SIGNED: Please sign and return one copy of this tran~'nJttal to $herrle at the above address. Thank you. ARCO Alaska, Inc. P.O. Box 100360, An Date: Subject: From/Location: Telephone: To/Location: August 4, 1994 Transmittal #: Kinley Caliper Survey's John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94071 Well Log Date Tool Type Contractor Number (M-D-Y) 6-1 7-4-94 Caliper Survey Kinle¥ 12-7 7-3-94 Caliper Survey f Kinley 12-11 6-29-94 I Caliper Survey i Kinle¥ 12-12 i 7-4-94 I Caliper Survey Kinley 12-32 l 6-30-94I Caliper Survey Kinley 13-12 6-30-94 Caliper Survey Kinley 14-10 7-1-94 I Caliper Survey I Kinle¥ 14-11 7-1-94i Caliper Survey I Kinley 16-20 i 7-3-94 J Caliper Survey I Kinle¥ 17-3 ! 7-2-94 Caliper Survey . Kinle¥ Number of Records: 10 rage, AK John E. DeGrey Distribution: Central Files State of Alaska ANO-8 Geology BPX Exxon Plea,~~ owledge re~~,~ by signing, and returning a copy o/~~" ~.'/ -L V~, ~jt,tal By:~~~ ~ /~~~ ~te: ~/~ 4~ n ~ ~" ARCO Alaska, Inc. Is a Subsidiary of AflanflcRIchfleldCompany ARCO Alaska, Xne. RECEIVED .,~mchorage, Alulm ~9510 DATE: APR 1 9 199 ~FE~NCE: ~CO C~ED HO~ F~ ~as~a Oil & Gas Cons, Commle~ton  -11 1-24-03 Pe~ Record A~~, -11 2-7-g3 Pe~ Record R~ 1, ~' 1-13 2-7-g3 Peff Record R~ 1, ~' ~1-24A 2-20-g3 Pe~ Record R~ 1, ~' ~~1-30 1-24-93 Pe~ Record R~ 1. ~' ~~ 2-14 7-27-91 T~ R~ 1.~' ~ ~ 3-9 12-19-92 Pe~ Record R~ 1. ~' ~-24 1-25-93 Pe~ Record R~ 1. ~' ~ID7/3-32 4-25-g2 PGST Computed Resets R~ 1, ~' ~3-32 4-25-g2 PSGT R~ 1. ~' ~3-34A 2-1g-g3 Pe~ Record R~ 1. ~ ~ ~ .4-35 8-16-g2 T~ R~ 1, ~' 8-18-92 T~ Boron ~Jection R~ 1, ~' ~~-4 2-22-93 Pe~ Record R~ 1. ~' .: 3-1-g2 PSOT Computed Resets R~ 1. ~' e- 7 5 W ~ ~g-27 3-1-92 ~GT 10 ~/~ R~ 1, ~' ~~ ~g-51 2-6-93 Pe~ Record R~ 1. ~' ~-51 2-8-g3 Pe~ Record R~ 1. ~' ~~11-1 4-21-92 PSGT Computed Resets R~ 1. ~' ~ ~11-13A 3-8-g3 Pe~ Record R~ 1. ~'  1-18 4-14-92 ~SGT Com~u~e~ Re~s R~ 1, ~' 1-15 4-14-92 PSGT R~ 1, ~' ~-~ ~12-4A 2-11-93 Pe~ Record R~ 1. ~' ~~~12-1g 2-11-g3 Pe~ Reco~ R~ 1, ~' ~ ~12-32 12-26-g2 Pe~ Record R~ 1. ~' ~'~ ~ ~14-5A 2-20-g3 Pe~ Record R~ 1. ~' ~' ~14-12 4-24-g2 PSGT Computed Resets R~ 1. ~' ~4-12 4-24-g2 PSGT R~ 1,  4-37 4-13-g2 PSGT Computed Resets R~ 1, ~' 4-37 4-13-92 PSGT R~ 1, ~' ~~16-21 7-23-92 PSGT Computed Resets R~ 1, ~' ~~ ~6-21 7-23-g2 PSGT R~ 1, ~' ~16-27 8-23-92 Pe~ Record R~ 1. ~' ~~ 16-30 2-12-g3 Pe~ Record R~ 1, ~' ~~7-21 12-20-g2 Pe~ Record R~ 1. ~' Pleue s~n ~d ret~e attached copy u receipt of data. Sonya W~ace ATO-1529 Tr~s~ 930 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON PHILLIPS MOBIL BPX STATE OF ALASKA * The correct api# for 3-32 is 50-029-21141-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-18-92 ARCO CASED HOLE FINALS 16-14 ... ~ 10-26-92 16-21 ~' ~ 10-27-92 17-10 Sf"~? 11-6.92 Prod Profile Run 1, 5" Prod Profile l~m 1, 5" Collar (Pack-off ~Ta~. mm 1, 5" Temperature Bun L 5" ~nJ Prome mm 1, 5" ~7~ mm 1, 5" Prod Profile ]~,_m L 5" Jewelry ~'" L 5" Prod Profile ]bm 1, 5" InJ Profile l~m L 5" Please sign and return the attached copy ,as receipt of dat~ RECEIVED BY DE ff ~ ~/~ ~. ---'-r~'t.-~.. ~- i v ~_- Have ANlce Day~ DEC ~) 0 1992 ~onya Wallace Alaska 0ii & Gas Cons. Commission APPROVED_ ATO- 1529 Anchorage Trans# 92266 # CENTRAL FILF~ # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL #PHILLIPS PB WELL ~ R&D #BPX # STATE OF ALAS~ TEXACO ARCO AI...A..?I(A, INC~ F:',. O, BOX t ~'")~')3(.'~(') A N C: I-'10 R A C; Ii'_", A !... A ;!;' !< A R E F:' Iii: I::..' E N C Iii: · A I:;.: C: O C A.'!-; E D I"! (1.11... IE F:' I N A I... 3' D I ,? 'i" Fi: I P.. i.J 'i" i 0 N 'i" !'-! E C i"} i:;, I::.: E C: 'i" Iii. D A F:' I :II: F: 0 R 'J 4 .... i (:;, 1 ,?;' RECEIVED MAI'{., ', 1991 Alaska Oil & Gas bi)liS, Commission Anchorage A i'i C FI 0 R A G E, A I_ A S K A DATE' 8-i 7-90 REFERENCE' ARCO CASED HOLE F'INAL. S .-i -:2 8- i O--90 4-i 8-i Z~-- 9 ¢, ~-ii '~ --' 96.', ,.~- _,~--i 4 '7-i i -ge ~- i 4 8- i i ---o (.) . 6-7 8-i i -90 ,=: 7-2 7-9o -'7-33 8- i i --90 ~-'~') 7-28-90 --9--42 i i-4 o .... 9-.-q'~ i i "- 23 8- i 2"" 90 ~.i~.°'-S2 T' .... 25-90 .. i' S '- 7 8 "- 5 '- 90 j ~"-t 2 8-4-'90 .4 7-'-~ 7-26-90 . ~'WDHi'-'~ 8-7-90 F'ERF' RECORD DUAL BURST TDT-P COLL_AR/PERF DIAGNOSTIC F'M PERF' RECORD CO L.L..AF'..' / f"ERF CNL.-C-;R/C f":L INJECTION PF:OF'I LE C'OLL..AR/PE]RF INJIECT!ON PROFILE CB i' CE'¥ C N L. --G R / C C L !.-.: 0 L_ t.. A R / F-' E J:...' F- F'RODLJC."F I ON PF.:OF'I L.E I', ~ r-ERF RFCORD D i A G N 0 ~-; T i C F H F'EF(F" RECOF,'D PRODLJC.'i" ]] ON PROF'II_E CCI_ I:'LEA~E SIGN ANi) RE"'TUF.:N i"HE ATTACi"iE~I) AUG 2 2 1990 SALLY HOF'F-E'CI< ER n T 0 = t 5 2 9 AI~I~.OII & Gas Cons. L;ommissWn RUN i , RUN t, RUN i , RUN i RUN i , RUN t , RUN i , RUN i , RUN i , RUN i, RLJN t , i;;i;J h,I 1 , F(" U N i, RUN RLJN i , R U N i., RUN i RUN i : RUH i RUN i: C:OPY AS.' RECEZF'T OF:' I)ATA,. A F' P R. 0 V E I;' 'i'RANS:~. 96'~.3 i ' ,5" SCH SCH A T L CAf, CO SCH ATLAS; A'f LAS C A I'~ C 0 A'¥LA,~¢ CAMCO 5'CFI S C H A'f' L A S A TI_ AS C n M C 0 SCH CAMCO SCH C A M C 0 A'FLAS DI£TRIBUTION _,E~TRAL FILES CHE"vRUN"-' D & M EXTEI'.~ION EXPLORATION EXXON MARATHON ~ MOB IL -.- F'HILLIF'& PB WELL. F'IL_ES R & D ,,-'"' BF'X -. ~I'A'T'E OF ALASKA TEXACO . THE AF'I~: FOR ti-23 I$ 50-029-21610. ** THE CORRECTED AF'I$ FOR t3-'7 IS 50-029-20650. --:. '" STATE OF ALASKA " I GIN A L ~ ALASKA ,JIL AND GAS CONSERVATION COMMIS WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL/~ GAS [] SUSPENDED ~J ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 89-11 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21910 4. Location of well at surface 1030' fSL, 125' fWL, Sec.17, TION, R15E, UN At Top Producing Interval 741' FNL, 2305' FEL, Sec.16, TION, R15E, UM At Total Depth 645' FNL, 1924' FEL, Sec.16, TION, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 1 2-32 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0ii Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 74' I ADL 28331 ~2. Date Spudded 13. DateT.D. Reached ]14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore I16. No. of Completions 02/15/89 03/12/89 j 06/14/89' N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+'I'VD){ 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13500'HD/9222'TVD 13455'MD/9191 'TVDI I YES,~ NO [] 2222' feet MD 1900' (approx) 22. Type Electric or Other Logs Run GR/D I L/D I EL/AL, GR/CNL/Z-Den/ML/Cal ~ CBT/CET/GR ~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP I BOTTOM HOLE SIZE CEMENTING RECORD 1 20" 91.5# H-40 13-3/8" 68.0/72,( # K-55/L-8 9-5/8" 47.0# L-80 12793 7" 29.0# L-80 13499 Surf 110' Surf l 4434 1 Surf ] 12480 '1 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Perforated w/4 spf, 120° phasing 12992'-13033'MD/8853'-8883'TVD 13037'-13072'MD/8886'-8912'TVD 13076'-13111'MD/8915'-8941'TVD 13116'-13126'MD/8945'-8952'TVD 13130'-13140'MD/8955'-8962'TVD 30" 17-1/2'~ 1 2-1/4' 8-1/2" 2150# Poleset 2500 sx CS III & 600 Top joh w/120 sx £~ I 500 sx Class O 350 sx Class G TUBING RECORD SIZE DEPTH SET (MD) b-]/2"/~-]/2 ' AMOUNT PULLED :ix Class G PACKER SET (MD) 12423' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. PRODUCTION TEST jMethod of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR IOI L-BBL GAS-MCF TESTPERIOD~ I : CALCULATED i~b I OIL-BBL GAS-MCF 24-HOUR RATE "~ I CORE DATA WATER-BBL WATER-BBL JCHOKESIZE ]GAS-OILRATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or Water. Submit core chips. None *Note: Drilled RR 3/15/89. Tubing run 3/26/89. (Dan1) WC6/056 Perforated well 6/14/89. RECEIVED AUG 2 8 989 Alaska 0il & Gas Cons. C0~missi0n Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Sadlerochit HOT OWC GEOLOGIC MARKERS MEAS. DEPTH 12927' 1~315' 13~54 ' TRUE VERT. DEPTH 8806' 9092 9120' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32~ I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~~~L~ Title Drilling Analyst Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. item 16 and 24: ~f this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ADDENDUM WELL: 3/17/89 12-32 RU Schl, rn CBT/CET/GR f/13,440'-9900' w/O psi & 1000 psi. Good cmt. Rn Gyro f/13,400'-surface. AUG 2 8 ~9 ~,/aska Oil & Gas Cons. Commission Anchorage Drilling Supervisor SUB.$URFAC DIRECTIONAL SURVEY I'~UIDANCE r~'iONTINUOUS I-flOOL R~CEIVED MAY 1 o ]98~ Company ARCO ALASKA, INC. Well Name D.S. 12-32 (1030' FSL,125' FWL,SEC 17,TION,,R, 15E,UM) F~oId/Locatiol3 PRUDHOE BAY~ NORTH SLOPE~ ALASKA Job Reference No. Date 73289 16-MAR-89 ~ Computed By; SARBER SINES SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCU ALASKA [NC. D.S. 12-32 PRUDHOE BAY NORTH SLOPEr ALASKA SURVEY DATE: 16-APR-S9 ENGINEER: G. SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- ~VERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 67 DES 25 MIN EAST ARCO ALASKA 1NC. D.S. 12-3Z PRUDHUE BAY NORTH SLOPE, ALASKA COMPUTATION OAT6: 19-APR-89 PAGE DATE OF SURVEY: 16-APR-SO KELLY 6USH[NG ELEVATION: ?4.00 FT ENGINEER: G. SAROER INTERPOLATED VALUES FOR EVEN 100 PEET OP MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OI$T. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -74.00 0 0 N 0 0 E 100.00 100.00 Z6oO0 0 I N 13 47 E ZO0oO0 ZO0.O0 126.00 0 I N 13 4 W 500.00 300.01 ZZ6.01 0 20 S 1~ 44 W 400.DO 400.00 326.00 0 15 S 46 51 E 500.00 500.00 426.00 1 30 N 75 47 E 600.00 599.91 525.9! 2 45 N 54 25 E 100.00 6'99.69 625.69 4 35 N 53 47 E ~00.00 799.21 725.21 6 38 N 66 ZO E 900.00 898.34 824.34 8 54 N 66 58 E 0.00 0.00 0.00 N 0.00 0.00 0.33 0.03 N 0.01 0.01 0.00 0.00 N 0.01 -0.21 0.25 0.21 S 0.14 -0.35 0.46 0.64. S 0.12 0.76, 2.06 0.63 5 1.09 4.52 1.53 0.77 N 4.58 10.83 2.15 3.56 N 10.24 20.7! 1.33 7.72 N 19.22 34.02 2.50 12.93 N 31.47 0.00 N 0 0 E 0.03 N 18 5~: W 0.01 N 79 57 E 0.25 S 33 53 W 0.65 S 10 13 W 1.26 S 59 47 E 4.64 N 80 25 ~ 10.85 N 70 49 E 20.71 N 68 7 E 34.02 N 67 40 E 1000.00 996.71 922.71 11 28 1100.00 1094.31 1020.37 13 16 1200.00 1191.41 1117.41 14 17 1300.00 lZ88.ZO 1214.20 15 0 1400.00 1384.47 1310.47 16 19 1500.00 1479.98 1405.98 18 4 1600.00 1574.Z0 1500.20 21 1700.00 1665.71 1591.71 25 46 1UO0. UO 1754.36 1680.36 29 11 1900.00 183~.87 1765.87 33 14 N 63 50 E 51.75 2.52 N 59 38 E 73.23 1.66 N 56 16 E 96.91 0.49 N 58 I 5 121.66 1.35 N 62 37 E 149.33 2.86 N 66 15 ~ 177.~6 2.29 N 68 7 E 211.47 4.57 N 68 26 E 251.77 3.76 N 68 37 E 297.91 3.47 N 68 54 E 349.59 4.65 20.26 N 47.62 E 51.76 N 66 56 E 30.54 N ~6.61 E 73.28 N 65 Z1 E 43.47 N 86.87 E 97.14 N 63 24 E 57.25 N 107.95 E 122.Z0 N 62 3 E 70.68 N 131.25 E 149.07 N 6'1 41 E 83.16 N 158.04 E 178.58 N 62 14 E 96.20 N 1~9.01 E 212.09 N 63 I E 111.03 N 226.50 E 252.25 N 63 53 E 127.92 N 269.44 E 298.27 N 6~ 36 E 146.6,4 N 317.63 E 349.85 N 65 13 E ZO00.O0 19Zl.43 1847.43 37 15 Z100.00 Z000.39 1926.39 38 ZZO0.O0 Z017.94 2003.94 40 7 Z3OO.OO 2152.85 Z078.86 43 7 Z400.O0 2ZZ3.00 2149.00 47 45 2500.U0 Z287.44 2Z13.44 51 45 2600.00 2348.06 2274.06 53 7 ZTUO.OU 2408.53 2334.53 52 Z7 Z800.00 2469.85 2395.85 51 56 ZO00.OO 2531.89 24.5 2'. 89 51 19 N 68 13 E 40'7.43 2.53 N 68 0 E 468.79 1.01 N 67 50 E 531.89 2.00 N 67 45 E 598.15 4.41 N 68 15 E 669.27 4.39 N 68 41 E 745.69 3.22 N 58 56 E 825.21 0.48 N 69 9 E 904.84 0.59 N 59 16 E 983.81 0.50 N 69 lB E 1062.14 0.62 167.74 N 371.49 E 407.61 N 65 41 E 190.64 N 428.43 E 468.93 N 66 0 E 214.36 N 486.91 E 532.00 N 6~ 14 E 239.41 g 548.25 E 598.25 N 66 24 E 266.03 N 614.20 5 669.34 N 66 34 E 294.07 N 685.30 E 745.73 N 66 46 E 322.81 N 759.48 ~ 825.24 N 65 58 E 351.28 N 833.88 f 904.~5 N 87 9 t 379.30 N 907.76 E 983.81 N 67 19 f 407.05 N 981.05 E 1062.14 N 67 27 E 3000.00 1594.75 2520.76 50 50 5100.00 2658.12 2584.12 50 30 3ZO0.O0 Z7Zl.93 2647.93 50 1Z 3500.00 27~6.15 Z2'lZ. 15 49 49 3400.00 2851.33 2777.33 48 55 3500.00 2917.20 2843.20 48 40 3600.00 Z983.53 2909.53 48 7 3700.00 3050.75 2976.75 4.7 30 3800.00 3118.56 3044.56 47 5 3900.00 3187.07 3113.07 46 24 N 89 Z8 E 1139.95 N 69 34 E 1217.19 N 59 39 E 1294.13 N 69 40 E 1370.75 N 70 14 {5 1446.48 N 70 50 {5 1521.63 N 70 50 E 1596.79 N 70 55 {5 1670.24 N 71 11 E 1743.58 N 71 25 E 1816.25 0.46 0.31 0.32 0.80 0.80 0.35 0.75 0.42 0.45 0.74 434.47 N 1053.91 E 1139.95 N 67 35 E 461.54 N 1126.31 E 1217.Zl N 67 43 488.33 N 1198.50 E 129~+.17 N 67 49 E 514.99 N 122'0.39 E 13r0.81 N 67 56 E 541.02 N 1341.58 E 1446.56 N 6'4 2 E 586.05 N 1412.57 E 1521.76 590.55 N 14~B.2~ E I5~6.47 N 6~ I7 E 614.82 N 1553.24 E 1670.49 N 6~ Z4 E 638.65 N 1622.75 E 1743.90 N 68 31 661.98 N 1691.75 E 1816.66 N 68 37 ARCO ALASKA INC. D.5. 12- 3:" PRUDHUE BAY NORTH SLOPE~ ALASKA COMPUTATI3N D~TE: 19-APR-89 DATE OF SURVEY: 16-APR-B9 KELLY ~USHING ELEVATLON: 74.00 FT ENGINEER: G. S~REE~ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED GEPTH TRUE SU~-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE MtASURkD YERIICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPIH DEPTH DEPTH DEG MIN DEG MIN FEET OEG/IO0 FEET FEET FEE'[ OEG MIN 40DO.OD 3256.39 3182.39 45 50 4100.00 3326.01 3252.01 46 0 4200.00 3395.19 3321.19 46 34 4300°00 3463.3~ 3389.36 &? 23 4400.00 3530.72 3456.72 47 52 4bO0.O0 3597.81 3523.81 47 58 4600.00 3663.99 3589.99 49 6 4700.00 3728.95 3654.95 49 52 4800.00 ~792.90 3718.90 50 35 ~."') 00. 00 3856.07 3782.07 51 3 N 71 47 E 1888.13 N 71 51 E 1959.67 N 73 4 E 2031.69 N 12 9 E 2104.58 N 72 28 E 2178.25 N 72 44 E 2252.09 N 71 45 E 2326.74 N 69 24 E 2402.69 N 67 30 E 2479.49 N 66 14 E 2557.00 0.51 0.39 0.85 0.71 0.58 0.90 2.03 I .32 I .88 I .00 684.72 N 17.60.15 E 1888.64 N 68 .44 E 707.10 N 1828.32 E 1960.29 N 68 51 E 729.47 N 1897.02 E 2032.44 N 68 57 E 751.94 N 1966.61 E 2105.47 N 69 4 E 774.44 N 2037.05 E 2179.29 N 6.9 11 E 796.54 N 2107.83 E 2253.31 N 69 17 E 819.20 N 2179.25 E 2328.14 N 69 23 E 8{4.66 N 2250.92 E 2404.18 N 69 25 E 8'72.76 N 2322.41 f 2480.99 N 69 24 E 903.34 N 2393.64 E 2558.43 N 69 19 E 5000.00 3918.20 3844.20 52 6 5100.00 3979.20 3905.Z0 52 39 5200.00 4039.45 3965.45 53 11 5300.00 ½099.46 4025.46 53 7 5400.00 4159.22 4085.22 53 23 5bO0.O0 ~218.64 4144.64 53 46 5600.U0 4277.37 420~.37 54 5'100.00 4335.55 4261.55 54 41 5800.00 ~393.03 4319.03 55 7 5900.00 44~9.89 4J75.89 55 N 64 31 E 2635.33 N 63 46 E 2714.42 N 63 47 E 2794.12 N 63 35 E 2874.00 N 63 27 E 2953.96 N 63 29 E 3034.17 N 63 33 e 3114.91 N 63 37 E 3196.08 N 63 40 E 3277.71 N 63 38 E 3359.80 1.63 0.66 0.51 0.10 0.70 0.31 0.48 0.61 0.07 935.97 N 2454.91 E 2636.63 N 69 12 ~ 970.66 N 2536.14 E 2715.55 N 69 3 E 1005.93 N 2607.78 E 2795.07 N 68 54 E 1041.37 N 2679.55 E 2874.80 N 6~ 45 E 1077.14 N 2751.28 E 2954.62 N 6~ 37 E 1113.04 N 2823.22 E 3034.71 N 68 29 E 1149.12 N 2895.66 f 3115.33 N 68 Zl E 1185.31 N 2968.52 E 3196.~1 N 68 14 E 1221.62 N 3041.82 E 3277.96 N 68 7 E 1258.13 N 3115.55 E 3359.99 Iq 68 0 E 6000.00 ~506.9~ 4432.98 54 16 6100.00 4566.91 4492.~)1 52 33 6200.00 4627.58 4553.58 52 53 6500.00 ~+6 87.42 4613.42 53 17 6400.00 47q, 7.52 4673.52 52 58 6500.00 4807.58 4733.58 53 11 6600.00 4867.65 4793.65 53 3 6 i'00.00 ,~917.40 4E) 53.40 53 26 6~00.00 49~7.27 4913.27 52 57 6900.00 5047.83 4973. I33 52 33 N 63 35 6: 3441.66 N 63 Z1 E 3521.55 N 63 15 E 3600.81 N 63 35 E 3680.77 N 63 42 E 3760.53 N 63 55 E 3840.40 N 64 0 E 3920.14 N 63 41 E 4000.21 N 63 44 E 4080.10 N 63 41 E 4159.53 3.11 0 I .OZ 1.11 0.30 0.64 0.60 0.45 0.56 O 1294.60 N 3139.03 t 3441.79 N 67 54 E 1330.31 N 3260.70 E 3521.63 N 67 48 ~- 1366.06 N 3331.67 E 3600.86 N 67 42 E 1401.94 N 3403.36 E 3680.80 N 67 36 E 1437.37 N 3475.00 E 3760.54 N 67 31 E I472.70 N 3546.81 E 3840.41 N 67 27 E 1507.7! N 3618.61 E 3920.1~ ~ 67 22 E 1543.10 N 3690.61 E &000.22 N 67 18 E 1578.55 fl 3762.39 E 4080.12 N 67 14 E 1613.79 N 3833.76 E 4159.57 N 67 10 E 7UO0.UO 5108.75 5031,. 73 52 23 71OO.UU 5169.80 5095. ~JO 52 25 IZO0.O0 5230.64 5156.64 52 39 7300.00 5291.00 5217.00 53 3 7400.00 5351.02 5277.02 53 5 IEO0=UU 5411.25 5337.75 52 44 7600.00 5471.4~ 5397.48 53 22 7TO0.UO 5530.44 5455.~+4 54 23 71~00. UO 55~;7.92 5513.92 55 78 ]'900.00 564~.59 5569.59 5~ 45 N 63 44 c 423'3.51 N 63 57 ~ 4317.67 N 64 11 E 4396.92 N 64 26 F 4476.55 N 64 29 E 4556.38 N 64 25 E 4636.07 N 64 36 E 4715.81 N 64 30 E 4796.54 N 64 24 E 487~.20 N 64 50 5 4961.20 0.26 0.33 0.2'5 O.Z1 0.25 0.53 0.90 1.08 1.5~+ 0.45 1648.91 N 3904.80 E 423~.67 N 67 6 E 1683.82 N 3975.90 E 4317.75 N 67 2 E 1718.53 N 4047.30 E 4397.04 N 65 59 t 1753.08 N 4119.17 E 4476.70 N 66 56 E 1787.50 N 4191.31 E 4556.55 N 65 54 E 1821.94 N 4263.29 E 4636.28 N 66 51 E 1856.30 N 4335.36 E 4716.06 N 65 49 ~ 1890.9~ N 4408.38 E 4796.83 N 65 46 E 1926.29 N 4482.1~ E 4878.53 N 66 44 E 1951.90 N 4557.21 E 4961.57 N 65 42 E ARCO ALASKA INC. D. 5. 12-32 PRUDHUE BAY NORTH SLOPE, ALASRA COMPUTATION DATE: 19-APR-89 PAGE DATE OF SURVEY: 16-APR-89 KELLY ~USHING ELEVATIUN: 74.00 FT ENGLN~ER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEa COURSE VERTZCAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. ,~Z[HUIH DEPTH DEPTH OEPTH DEG MIN DEG MYN FEET DEG/IO0 FEET FEET FEET DEG ~Iq 8000.00 5698.31 5624.31 56 37 N 65 ~ E 5044.77 8100.00 5753.83 5679.83 56 9 . N 65 15 E 5127.95 8ZO0.O0 5809.65 5735.65 55 55 8500.00 5865.97 5791.97 55 32 8~00.00 5922.77 5848.77 55 14 8500.00 5979.83 5905.83 55 7 8600.00 6037.19 5963.19 54 53 8100.00 6094.92 6020.92 54 36 8800.00 6153.02 6079.02 54 16 8900.00 6211.79 6137.79 53 44 N 65 21 E 5210.89 N 55 14 E 5293.48 N 65 I E 5375.66 N 64 55 E 5457.70 N 64 57 E 5539.53 N 64 56 E 5621.17 N 64 43 E 5702.45 N 64 38 E 5783.28 9000.00 6271.31 6197.31 53 11 9100.U0 6331.6Z 6257.62 52 41 9200.00 6392.67 6318.67 52 0 9300.00 6454.42 6380.42 51 44 9~00.00 6516.66 6442.66 51 1Z 9500.00 6579.59 6505.59 50 49 9600.00 6643.08 6569.08 50 22 9700.00 6707.07 6%33.07 50 B 9800.00 6771.25 6597.25 49 56 9900.00 6835.47 6761.47 50 13 N 64 34 E 5863.53 N 64 23 E 5943.23 N 64 13 E 6022.24 N 64 5 E 6100.80 N 63 54 E 6178.88 N 63 36 E 6256.46 N 63 13 E 6333.57 N 63 1 E 6410.23 N 63 ! ~ 6486.58 N 63 12 E 6563.06 10000.00 6899.35 6825.35 50 25 10100.00 6962.8~ 6888.94 50 45 IOZO0.O0 7025.90 6951.90 51 4 10300.00 7088.52 7014.52 51 24 10400.0U 7150.64 7076.64 51 48 10500.00 7212.08 7138.08 52 15 10600.00 7273.14 7199.14 52 31 10700.00 7333.86 7259.86 52 44 10800.00 7394.48 7320.~8 52 26 10900.OO r455.97 7381.97 51 44 N 63 31 E 6639.82 N 64 11 E 6716.92 N 64 45 E 679~.46 N 65 21 E 6872.35 N 65 54 E 6950.65 N 66 24 E 7029.54 N 66 ~ E ?I08.73 N 66 40 E 7188.19 N 66 42 E 7267.65 N 67 9 E 7346.53 I .32 0.13 0.41 0.45 0.21 0.26 0.25 0.42 0.52 0.5~ 0.71 0.45 0.44 0.35 0.54 0.56 0.33 0.27 0.16 0.24 0.61 0.55 0.56 0.60 0.71 0.35 0.26 0.62 0.92 0.49 1997.31 N 4652.99 E 5045.18 N 66 40 E 2032.25 N 4708.54 E 5128.39 N 66 39 E 2066.90 N 4783.96 E 5211.37 N 66 38 E 2101.41 N 4859.06 E 5294.00 N 66 36 E 2136.00 N 4933.6B E 5376.21 N 66 35 E 2170.76 N 5008.07 E 5458.30 N 66 33 E 2205.46 N 5082.26 E 5540.17 N 66 32 E 2240.01 N 5156.31 E 5621.85 N 66 31 E 2274.60 N 5229.95 E 5703.17 N 66 29 E 2309.20 N 5303.1'1 E 5784.06 N 66 28 E 2343.66 N 5375.69 E 5864.36 N 66 26 E 2378.05 N 5447.70 E 5944.12 N 66 25 E 2412.36 N 5519.00 E 6023.19 N 66 23 E 2446.6'7 N 5589.81 E 6101.~2 N 66 Z1 E 2480.92 N 5660.14 E 6179.98 N 66 19 5 2515.29 N 5729.87 E 6257.6~ N 66 17 E 2549.88 N 5798.99 E 6334.83 N 66 15 E 2584.64 N 5867.56 E 6411.60 N 66 13 E 2619.40 N 5935.79 E 6488.06 N 66 11 E 2654.09 N 6004.19 E 6564.64 N 66 9 E 2688.61 N 6072.97 E 6641.51 N 66 7 E 2722.65 N 6142.31 E 6718.69 N 66 5 E 2756.11 N 6212.38 E 6796.31 N 65 4 E 2788.9? N 6283.07 f 6~?~.25 N 66 3 E 2821.28 N 6354.43 E 6952.58 N 66 3 E 2853.17 N 64Z6.61 E 7031.49 N 66 3 E 28~4.70 N 6499.26 E 7110.69 N 65 3 5 2916.20 N 6572.21 E 7190.15 N 66 4 E 2947.62 N 6645.21 E 7269.62 N 65 4 E ~978.53 N 6717.78 f 7348.48 N 66 5 E llO00.O0 7518.54 7444.54 50 32 11100.00 7582.73 7508.73 49 50 IIZO0.OO 76~7.22 7573.22 49 48 11300.00 7711.86 7637.86 49 39 11400.00 7776.64 7702.64 49 41 11500.00 7841.26 7767.26 49 44 11600.U0 1905.8~ 7831.86 ~9 50 11700.00 1970.24 7896.24 49 58 11800.00 8034.64 7960.64 49 45 11900.00 8099.49 8025.49 ~9 26 N 67 25 E 7424.55 N 67 39 E 7501.20 N 67 38 E 7577.59 N 67 32 E 7653.96 N 67 25 E 7730.16 N 67 2~ E 7806.48 N 67 23 E 7882.78 N 67 1T E 7959.33 N 67 33 E 8035.76 N 57 41 E 8111.96 1.88 0.20 0.05 0.25 0.17 0.11 0.36 O.ZO 0.37 0.32 3008.69 N 6789.73 E 7426.4:3 N 66 6 F 3037.93 N 6860.59 E 7503.12 N 66 6 E 3066.96 N 6931.25 E 7579.48 N 66 7 E 3096.06 N 7001.85 E 7655.82 N 66 8 E 3125.27 N 7072.24 E 773Z.00 N 66 9 E 3154.54 N 7142.72 E 7808.~0 N 6,5 10 E 3183.81 N 7213.18 E 7884.58 N 66 11 E 3213.31 N 72.33.82 E 7961.12 N 66 11 E 3242.71 N 735~,.37 E 8037.5", N 66 12 E 3271.67 N 7424.85 E 8113.71 N 65 13 E COMPUTATION D~TE: 19-APR-89 PAGE ARCU ALASKA INC. D.S. 12-32 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 16-APR-89 KELLY BUSHING ~L~VATION: 74.00 FT ENGINEER= G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUb SUB-SEA COURSE MtASURtD VERTICAL VERTICAL DEVIATION AZIMUTH O~P'[H DEPTH OEPIH DEG NIN DEG MIN VERTICAL DOGLEG RECTANGUL&R COORDINATES HgRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH FEET DEG/IOO FEET FEET FElfT DEG MIN 12000.00 8164.77 8090.77 49 Z 12100.00 8230.65 8156.65 48 35 1ZZO0.OO ~a ~J6.95 8ZZZ.95 48 19 1Z300.00 8363.80 8289.80 47 43 12400,.00 8431.64 8357°64 46 45 1ZbO0.OO 8500.47 8426.47 46 17 1Z600.00 8570.18 84,96°18 45 13 1Z700.00 8641.04 8567.04 44 25 1ZBO0.O0 8713.29 8639.29 43 17 IZ900.00 8785.89 8711.89 43 26 N 67 52 E 8187.73 N 58 13 E 8262.92 N 68 43 E 8337.78 N 59 13 E 8412.09 N 70 45 E 8485.52 N 71 55 E 8557.8:7 N 73 1Z E 8629.26 N 74 49 E 8699.38 N 76 29 {5 8767.80 N 76 44 E 8835.66 0.65 0.33 0.48 1.12 I .82 1 1 1.91 1.04 0.95 3300.34 N 7494,99 E 8189.46 N 66 14 3328.44 N 7554.74 E ,9_264.61 N 66 15 3355.93 N 7634.38 E 8339.43 N 66 16 E 3382.6~ N 7703.74 E 8413.69 N 66 17 E 3407.93 N 7772.77 E 8487.04 N 66 19 E 3431.06 N 7841.50 E 8559.28 N 66 22 3452.5'5 N 7909.88 E ~630.55 N 66 25 E 3472.04 N 7977.73 E 8700.53 N 66 28 3489.13 N 9044.72 E ~9768.78 N 66 33 E 3504.82 N 8111.68 E ~836.47 N 66 37 E 15000.00 8859.12 8785.12 42 30 13100°00 893Z.76 8858.76 42 41 13ZOO.U0 9006.37 8932.37 42 24 13JO0.UO 9080.47 9006.47 42 4 13400.00 915Z.84 9078.84 45 53 13500.00 9222.41 9148.41 45 55 N 75 54 E 8902.89 N 75 39 E 8969.85 N 75 26 E 9036.83 N 75 46 E 9103.33 N 76 16 E 9171.52 N 76 16 E 9242.49 0.48 0.25 0.30 0.45 0.02 0.00 3520.90 N 31'77.82 E 8903.56 N 66 ~2 E 3537.54 N 8243.41 E 8970.~0 N 66 46 E 3554.47 N 8308.92 E 9037.2~ N 66 50 E 3571.22 N 8373.98 5 9103.69 N 66 54 E 3587.85 N 8440.91 E 9171.79 N 66 58 E 3604.90 N ~510.69 5 9242.68 N 67 2 5 A~CO ALASKA INC. U.5. 12-32 PRUOHOE 8AY NORTH SLOPE~ ALASKA CDMPUTATI?N DATE: 19-APR-89 PAGE DATE DF SURVEY: 16-APR-B9 KELLY BUSHING ELEVATION: 14.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HURIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH ERST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -74.00 0 0 1000.00 996.71 922.71 11 28 ZOOO.O0 1921.43 1847.43 37 15 3000.00 2594.76 :2520.76 50 50 4000.00 3256.39 3182.39 45 50 5000.00 3918.20 3844.Z0 52 6 6000.00 4506.98 4432.98 54 16 7000.00 5108.73 5034.73 52 23 8000.00 5698.31 5524.31 56 37 9000.00 6271.31 6197.'31 53 11 N 0 0 E 0.00 N 63 50 E 51.75 N 68 13 E 407.43 N ,59 26 E 1139.95 N 71 47 E 1888.13 N 64 31 E 2635.33 N 63 35 E 3441.66 N 63 44 E 4238.61 N 65 4. E 5044..77 N 64 34 E 5863.53 0.00 2.5Z 2.53 0.4.6 0.51 I .63 3.11 0.26 I .32 0.71 0.00 N 0.00 E 0.00 N 0 0 E 20.26 N 4.7.62 E 51.76 N 66 56 E 167.7~+ N 3'11.49 E 407.61 N 65 61 E 434.47 N 1053.91 E 1139.95 N 67 35 684.72 N 1760.15 E 1888.64 N 68 44 935.97 N Z454.91 E Z636.63 N 69 12 E 1294.60 N 3189.03 E 3441.79 N 67 54 1648.91 q 3904.80 E 42.38.67 N 67 6 E 1997.31 N 4632.99 E 5045.18 N 65 40 E 2343.66 N 5375.69 E 5864.36 N 66 26 E 1OOOO.OO 6BgcJ. 35 6825.35 50 25 11000.00 7518.54 T~44.54 50 32 12000.00 ~164.7'1 8090.77 49 Z 13000.00 8859.1Z 8'T85.12 42 30 13500.00 92Z2.41 9148.4.1 45 55 N 63 31 E 6639.82 N 67 25 E 7424.55 N 67 52 E 8187.73 N 75 54 E 8902.89 N 76 16 E 9242.4.9 0.61 1.88 0 0 0.00 2688.61 N 5072.97 E 6641.51 N 65 7 E 3008.69 N 6789.73 E 7426.49 N 66 6 E 3300.34 N ?494.99 E B189.46 N 65 14 E 35Z0.90 N .~I?7.BZ E ~903.56 N 65 42 E 3604.90 N 8510.69 E 9242.6~J N 67 2 E ARCO ALASKA INC. D.S. 12-3Z PRUOHOE BAY NURTH SLOPEm ALASKA COMPUTATION DATE: 19-APR-B9 DATE OF SURVEY: 16-APR-89 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: G. S~RBE~ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRU~ SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEC'TION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET PEET FEET DEG MIN 0.00 O.OO -74.00 0 0 N 0 0 E 74.00 74.00 0.00 0 3 N 0 35 E 174.00 174.00 100.00 0 ! S 42 3 E Z74.0U Z74..00 200.00 0 14 S 30 9 W 3'14.00 374.00 300.00 0 11 S 22 29 E 474.00 474.00 400.00 0 59 N 83 53 E 574.04 514.00 500.00 2 25 N 65 38 E 674.21 6'74.00 600.00 4 4 N 63 39 E 774.65 774.00 700.00 6 14 N 65 50 E 875.39 874.00 800.00 8 15 N 67 7 5 0.00 0.00 0.00 N 0.00 E -0.01 0.05 O.Ot N 0.01 W 0.00 0.12 0.00 N 0.00 E -0.11 0.48 0.08 S O.OB W -0.38 0.38 0.56 S 0.17 W 0.21 2.00 0-74 S 0.53 E 3.35 1.16 0.28 N 3.52 E 8.89 1.84 2.70 N 8.50 E 17.87 1.88 6.57 N 16.62 E 30.36 2.81 11.50 N 28.10 E 0.00 N 0 0 E 0.01 N 64 21 W 0.00 N 81 21 E 0.12 S 45 32 W 0.59 S 17 13 W 0.91 S 35 37 E 3.53 N 85 30 E 8.92 N 72 22 E 17.87 N 68 26 E 30.35 N 67 44 E 976.83 9~4..00 900.00 10 56 1079.09 1074.00 1000.00 12 58 1182.06 1174.00 1100.00 14 12 1Z85.50 1274.00 1ZOO.D0 14 51 1589.05 1374.00 1300.00 16 8 1493.70 1474..00 1400.00 17 55 1599.79 1574.00 1500.00 21 35 1'I09.19 1674.00 1600.00 26 7 1822.61 1774.00 1TO0.O0 30 0 194.1.23 1874.00 1800.00 35 7 N 64 49 E 47.26 2.18 N 60 27 E 68.53 1.72 N 56 ZZ E 92.56 0.51 N 57 34 E 117.94 1.28 N 61 53 E 145.26 3.08 N 66 11 E 175.91 2.15 N 68 7 E Zll.39 4.57 N 68 26 E 255.74 3.62 N 68 40 E 309.07 3.69 N 68 4¢ E 372.72 4.55 18.31 N 43.56 E 47.26 N 67 12 28.17 N 62.50 E 68.56 N 65 44 41.0Z N 83.19 E 92.75 N 63 45 55.23 N 104.75 E 118.43 N 62 12 69.29 N 128.51 E 146.00 N 61 39 82.37 N 156.26 E 176.64 N 62 12 96.19 N 188.94 E Z1Z.01 N 63 1 112.49 N 230.19 E 256.20 N 63 57 131.99 N 279.84 E 309.4.1 N 64. 44 155.01 N 339.20 E 372.94 N 65 26 Z066.4.7 1974.00 1900.00 38 1 Z194o83 Z074..00 ZO00.O0 40 1 Z329.30 2174.00 ZIO0.O0 44 ZT 2478.36 2274.00 2200.00 51 1 2643.09 2374.00 2300.00 52 51 ZB06.75 Z474.00 2400.00 51 54 2967.0~ 2574.00 2500.00 50 59 3124.90 Z674.00 2600.00 50 25 3281.15 Z774.00 2700.00 49 55 3434.46 2874..00 2800.00 48 49 N 68 Z E 448.13 N 67 50 E 528.54 N 67 54 E 618.42 N 68 36 E 728.74 N 69 Z E 859.59 N 59 15 E 989.12 N 69 23 E 1114.38 N 69 36 E 1236.38 N 69 39 E 1356.33 N TO 30 5 1472.42 0.42 1.96 4.84 3.81 0.83 0.43 0.31 0.55 0.57 182.90 N 409.27 E 448.Z8 N 65 55 E 213.10 N 483.80 E 528.65 N 66 13 E 247.05 N 567.03 E 618.51 N 66 Z7 E 287.89 N 669.52 E 728.79 N 66 43 E 335.14 N 791.59 E 859.61 N 67 3 5 381.18 N 912.72 E 989.12 N 67 19 E 425.47 N 1029.97 E 1114..J8 N 67 33 E 468.22 N 1144.31 E 1236.40 N 67 44 E 509.97 N 1256.86 E 1356.3~ N 67 54 F 549.75 N 1366.05 f 1472.52 N 65 4 E 3585.69 2974.00 2900.00 48 13 ' 3134.36 5074.00 3000.00 4.7 22 .~881.05 311'4.. 00 3100.00 46 32 4.025.26 3274..00 3Z00.00 45 48 4169.27 33 i'4.00 3300.00 46 21 4515.14 34'14.00 3400.00 47 29 4.464.5~ 35?4.00 3500.00 47 49 4615.30 3674.00 3600.00 49 13 4770.25 3774.00 3700.00 50 22 ~9Z9.66 3874.00 3800.00 51 19 N 70 51 E 1585.63 N 71 3 E 1695.51 N 71 22 E 1802.56 N 71 48 E 1906.18 N 72 0 E 2009.50 N 72 10 E 2116.14 N 72 44 E 2225.86 N 71 Z1 E 2338.31 N 58 10 E 2456.58 N 65 50 E 2579.34 0. '15 0.43 0.80 0.28 0.69 0.66 0.76 2.24 1.87 . 1.62 587.06 N 1473.15 E 1535.B1 N 68 16 E 623.05 N 1577.18 E 1695.78 N 6~ 26 E 657.61 N 1678.74 E 1802.95 N 68 36 5 690.38 N 1777.35 E 1906.72 N 6~ 46 E 722.61 N 1875.84 E 201O.Z1 N 68 55 E 755.49 N 1977.66 E 2117.05 N 69 5 E 788.72 N 2082.68 E 2227.02 N 69 15 E 822.91 N 2190.Z4 E 2339.73 N 69 24 E 864.14 N 2301.19 E 2458.09 N 69 25 E 912.45 N 2414.05 E 2580.73 N 69 17 E ARCO ALASKA 1NC. U.S. 1Z-3Z PRUOHOE BAY NURTH SLOPE, ALASKA COMPUTATION DATE: 19-APR-B9 PAGE D~TE UF SURVEY: 16-APR-B9 KELLY BUSHING ELEVAIION: 74.00 PT ENGINEER: G. SARBE~ INTERPOLATED VALUES FOR EVEN 100 PEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MtASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/tO0 FEET FEET FEEl DEG MIN 5091.41 3974.00 3900.00 52 35 5Z57.65 4074.00 4000.00 53 6 b4Z4.78 4174.00 4100.00 53 24 5594.24 4274.00 4200.00 54 10 5166.13 4374.00 4300.00 54 57 5942.EY 4474.00 4400.00 55 26 6111.66 4574.00 4500.00 52 34 6277.49 ~674.00 4600.00 53 25 64~4.01 47?4.00 4700.00 53 7 6610.58 4874.00 4800.00 53 7 N 63 46 E 2707.61 N 63 43 5 2840.15 N 63 ZB E 2973.80 N 63 32 E 3110.25 N 63 38 E 3Z50.53 N 63 37 E 3394.82 N 63 19 E 3530.78 N 63 29 E 3662.81 N 63 46 E 3795.60 N 63 57 E 3928.59 6777.87 4974.00 4900.00 53 4 6943.02 50'14.00 5000.00 52 27 1106.88 51'/~.00 5100.00 52 26 7Z71.78 5274.00 5200.00 52 57 7~38.Z2 5374.00 5300.00 53 0 7604.ZZ 5474.00 5400.00 53 24 7?75.53 5574.00 5500.00 55 g 7955.64 5674.00 5600.00 56 55 8136.Z0 5774.00 5700.00 56 7 8514.Z0 5874.00 5800.00 55 Z8 N 63 43 E 4062.51 N 63 42 E 4193.54 N 63 58 E 4323.12 N 64 22 E 4454.00 N 64 25 E 4586.92 N 64 37 E 4719.18 N 64 22 E 4858.13 N 64 59 E 5007.80 N 65 19 E 5157.97 N 65 12 E 5305.17 U489.81 5974.00 5900.00 55 8 8663.82 6074.00 6000.00 54 43 8835.U9 61f4.00 6100.00 54 6 9004.48 6Z74.00 6Z00.00 53 9 9169.6Z 6374.00 6300.00 52 11 9~31.b8 6474.00 6400.00 51 35 9491.16 6514.00 6500.00 50 50 ~648.40 6674.00 6600.00 50 14 9804.27 6774.00 6700.00 49 56 9960.Z3 6874.00 6800.00 50 17 N 54 55 E 5449.35 N 64 58 E 5591.68 N 54 41 E 5731.47 N 64 33 E 5867.11 N 64 16 E 5998.31 N 64 4 E 6125.53 N 63 37 E 6249.62 N 63 7 E 6370.66 N 63 1 E 6489.84 N 63 21 E 6609.28 10111.67 6974.U0 6900.00 50 4~ 10276.72 7074.00 7000.00 51 18 10~37.84 7174.00 7100.00 52 3 10601.~1 7274.00 7200.00 52 31 lU166.31 7374.00 7300.00 52 39 10929.08 7474.00 7400.00 51 35 11086.51 75?4.00 7500.00 49 49 llZ~I.~] ~614.00 7600.00 49 46 11395.91' 7774.00 7700.00 49 41 N 64 17 f 6]'30.57 N 65 14 E 6854.18 N 66 6 E 6980.43 N 66 35 E 7109.85 N 66 41 E 7240.91 N 67 13 E 7369.34 N 67 39 E 7490.B7 N 67 36 E 7609.29 N 67 25 E 7727.04 11550.65 ?874.00 7800.00 49 44 N 67 27 E 7845.09 0 0.36 0.25 0.26 0.39 0 0.42 1.0.4 0.55 0.73 0.53 0.19 0.34 0.42 0.49 0.89 1.22 0.80 0.45 0.25 0.34 0.47 0.74 0.77 0.57 0.5Z 0.40 0.19 0.40 0 0.61 0.90 0.25 0.58 0.66 0.26 0.18 0.18 0.16 967.6~' N 2530.01 E 2708.74 N 69 4 E 1026.33 N 2649.15 E ZBkl.0Z N 68 49 E 1086.02 N 2769.07 E 297~..43 N 68 35 E 1147.04, N 2891.47 E 3110.6B N 68 21 ~ 1209.53 N 3017.41 E 3250.80 N 68 9 E 1273.71 N 314.6.99 E 3394.98 N 67 57 E 1334.47 N 3268.97 E '3530.86 N 67 47 E 1393.91 N 3387.24 E 3652.83 N 67 37 E 1452.94 N 3506.51 E 3795.60 N 67 29 E 1511.43 N 3626.21 E 3928.59 N 67 22 E 1570.75 N 3746.58 E 4061'.52 N 67 15 E 1628.90 N 3864.31 E 4193.59 N 67 8 E 16B6.2Z N 3980.80 E 4323.21 N 67 2 E 1743.32 N 4098.80 E 4454.14 N 66 57 E 1800.63 N 4218.91 E 4587.11 N 6-6 53 E 1857.75 N 4338.41 E 4719.43 N 66 49 E 1917.59 N 4464.02 E 4858.45 N 66 45 E 1981.66 N 4599.46 E 5008.19 N 65 41 E 2044.81 N ~.735.84 E 5158.43 N 66 38 E Z106.31 N 4869.68 E 5305.69 N 66 36 E 2167.21 N 5000.50 E 5449.~4 N 66 34 E 2227.53 N 5129.57 E 5592.35 N 66 31 E 2287.01 N 5256.22 E 5732.21 N 66 29 E 2345.20 N 5378.93 E 5867.95 N 66 26 E 2401.95 N 5497.4Z E 5999.25 N 66 23 E 2457.49 N 5612.10 E 6126.57 N 66 21 E 2512.24 N 5723.72 E 6250.7~ N 66 18 E 2566.67 N 5832.17 E 6371.98 N 66 14 E 2620.88 N 5938.71 E 6491.32 N 66 11 E 2674.93 N 6045.5B E 6610.93 N 65 7 E 2728.59 N 6154.63 E 6732.36 N 66 5 E 2781.38 N 6266.54 E 6856.06 N 66 3 E 2833.40 N 6381.65 E 6982.38 N 66 3 E 3885.14 fl 6500.29 E 7111.81 N 66 3 E 2937.05 N 6620.65 E 7242.87 N 66 4 E 2987.37 N 6738.80 E 7371.29 N 66 5 E 3034.01 N 5851.04 E 7492.79 N 66 6 E 3079.01 N 5960.57 E 7611.17 N 66 8 E 3124.07 N 7069.35 E 7728.89 N 66 9 E 3169.35 N 7178.38 E 7846.~1 N 66 10 E COMPUTATION DATE: 19-APR-g9 PAGE ARCO ALASKA INC. D. S. 12-3Z PRUDHOE BAY NORTH SLOPE. ALASKA DATE DF SURVEY: 16-APR-B9 KELLY BUSHING ELEVATION: 7,4.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ME&SURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY N~RTH/SOUTH EAST/WEST DIST. AZZMUTH FEET DEG/[O0 FEET PEET FEET DEG MIN 11705.85 '1974.00 7900.00 49 57 11860.75 8074.00 8000.00 49 34 1Z014o09 8174.00 8100.00 48 57 1Z165.45 8Z'/'4 · OO 8200.00 48 25 lZ315.14 83'r4. O0 8300.00 47 35 12461.66 8474.00 8400.00 &6 25 12605.43 85 14.00 8500.00 45 10 lZ 74,5.91 8674.00 8600.00 43 44 12883.65 8774. O0 8700.00 43 33 13020.17 8874.00 8800.00 42 28 N 67 17 E 7963.80 N 67 40 5 BOBZ.07 N 67 56 E 8198.36 N 68 33 E 8311.96 N 69 23 E 8423.28 N 71 34 5 8530.21 N 73 16 E 8633.10 N 75 37 5 8731.00 N 76 50 E 8824.56 N 75 48 E 8916.36 O.Zb 0.37 0 0.EZ 1.3Z I .32 1.06 1.78 0.47 0.37 3215.04 N 7287.94 E 7365.59 N 65 11 E 3260.33 N 7397.20 E 8083.83 N 66 12 E 3304.35 N 7504.84 E 8200.08 N 66 14 E 3346.51 ,q 7610.33 ~ 3313.6Z N 66 15 E 3386.65 N 7714.20 E 8424.87 N 66 17 E 3422.36 N 7815.16 E ~J531.66 N 66 21 E 3453.66 N 7913.58 5 8634.38 N 66 25 E 3480.12' 4q 8008.59 E 873Z.07 N 66 30 E 3502.25 N 8100.74 E 8825.40 N 66 37 ~ 3524.23 N 8191.0:) E 8917.01 N 66 43 E 13156.08 89'?4.00 8900.00 42 36 13Z91.31 90)4.00 9000.00 42 3 13500.00 9222.41 9148.41 45 55 N 75 Z8 E 9007.&6 N 75 44 E 9097.56 N 76 16 E 9Z4Z.49 0.36 0.45 0.00 3547.01 N 8280.21 E 9007.95 N 66 ~B 5 3569.78 N 8368.33 E 9097.92 N 66 53 E 3604.90 N 8510.69 E 924Z.68 N 67 Z E ARCO aLA5KA D.S. 12-3Z PRUDHOE BAY NORTH 5LOPE, ZNC. ~LA5KA COMPUTATION D.~TE: 19-APR-89 DATE KELLY BUSHING OF SURVEY: ELEVATION: ENG.IN~kR: PAGE 16-APR-B9 74.00 FI MARKER SAG SHUBLIK TOP SADLEROCHIT ZONE 4 ZONE 3 ZONE 2 HOT GCT LAST READING PBTD TD INTERPOLATED VALUES SURFACE MEASURE9 OEPTH BELOW KB 12791.00 12824.00 12927.00 12927.00 13178.00 13273.00 13315.00 13354.00 13400.00 13455.00 13500.00 FOR CHOSEN LOCATION TVD FROM KB 8706.74 8730.7q 8805.52 8805.52 8990.11 9060.40 9091.57 9120.15 9152.84 9191.10 9222.41 HORIZONS 1030' FSL, & lZ5' FW L, SEC17, TION~ R15E 8632.74 3487.68 N 8038.71 E 8656.74 3492.93 N 8060.74 E 8731.52 3509.10 N 8129.59 E 8731.53 3509.10 N 8129.69 E 8916.11 3550.'~3 N 8294.54 E 8986.40 3566.75 N 8356.42 E 9017.57 3573.59 N 8383.76 E 9046.15 3580.13 N 8409.48 E 9078.84 3587.85 N 8440.91 E 9117.10 3597.23 N 8479.29 E 9148.41 3604.90 N 8510.69 E RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST ARCU RLRSKA D.S. 12-32 PRUDHOE BAY NURTH SLOPE, 1NC. AL&SKA COMPUTATION DATE: 19-APR-89 KELLY DATE OF SURVEY: BUSHING ELEVATLON: ENGINEER: PAGE 16-APR-Sg 74.00 FT G. SARBE,R MARKtR SAG SHUBLIK 'TOP SADLERUCHIT ZONE 4 ZONE 3 ZONE Z HOT OWC PBTD TD ~~~ STRATIGRAPHIC SURFACE MEASURED DEPTH BELOW KB 12791.00 12824.00 12927,00' 12927.00 13178.00 13273.00 13315.0O 13354~00 13~55.00 13500.00 SUMMARY LOCATION : TVD FROM KB 8706.7q 8730.74 8805.52 8805.52 8990.11 9060.40 9091.57 9120.15 9191.10 9222.41 1030' FSL, SUB-SEA 8632.74 8656.74 8731.52 8731.52 8916.11 8986.40 9017.57 9046.15 9117.10 9148.41 1125' FWL, SEC1T, TION~ R15E RECTANGUL,~R COORD NORTH/SOUTH EAS 3487.68 N 803 3492.93 N 806 3509.10 N 812 3509.10 N 81Z 3550.73 N 829 3566.75 N 8~5 3573.69 N 838 3580.13 N 840 3597.23 N 847 3604.90 N 851 IN~TES T/WEST 8.71 E 0.74 E 9.69 E 9.69 5 4.54 E 6.½2 E 3.76 E 9.48 E 9.29 E 0.69 E ~IN~L WELL LOCATION AT TO: IRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DIST&NCE AZIMUTH FEET DEG MIN 13500.00 9222.~1 9148.41 9Z42.68 N 67 Z E SCHLUMBER©ER El I.RFC T T ON~L SURV E Y COMPANY ARCO ALASKA INC. NELL 0 .S. 12-82 FIELD PRUOHOE BAY COUNTRY USA RUN OATE ONE L OOOED i8 - APR - 89 REFERENCE ?9289 WELL · (1030' FSL, 12-32 125' FWL, SEC 17, TION, R15E, UM) HORIZONTAL PROJECTION NORTH !0000 REF 8000 6000 4000 2000 -2000 -4000 SOUTH -6000 NEST 79289 SCALE : !/2000 [N/FT -4000 -2000 0 2000 4000 6000 8000 ! 0000 2000 EAST WELL · (103'0' D..S. FSL, 12-32 125' FWL, SEC 17, TION, R15E, UM) VERTICAL PROJECTION 2~47. -4000 -2000 O O .... ~----~---:----4-..; ...; ....... ~ ....... ~; ~ ~: ~ "-'?-=-:"'r"'T'"~'"?"=-?'- ':" ~"'T"'T""["-~'"T'"~'- :::::::::::::::::::::::::::::::::::::::::: ..; ~.: . · . , ..... ';Z:~:ZZ::i;;2:::!:::i:=:: ..-t.--~-.4----!-+.+---i..-? ..... ....L.:L.~...-.."....j._~_.-~ .... "' ?"F".;Y"?"t'¥' :'"='".."' .... · . . , . , ...~,...;...;..;..;..: .~..,. :, , ~ .:., ...+...+..?....i....;....r...4..,~l.+..' ..;..-~...;...-i...4....,....L.. -.'5--.5-.+..4--+-.+-.-; ........ *-.- ...i...?....~....;._ f...;....~. :~... . . ~' '~! ' ....~ ......... u..:...L...:.._~.~ ..... L...L..L...L..i....L._L_=...L .... ' : ....... · ?-..? ........ ,..?.?..,...~ ........ "'!'"?'=': ":'.'":-'"O¢ ' ' .... ;;. ... ::... ::..--!.-..i...~....;....=:~ ......... ~....~;...?.~.+..;...~... . . -.-4...4....:.-...~...4..-:....4....;...; ,_¢~....~ . . . -.-T..T...!...T..T..T....? .... , , : : ~. ?~? . ~ ~ .... ;'-?-'- 2000 4000 6000 8000 10000 . , ....... · --f-".?'---!'"-i-.4.---:,--.! ........ ~- PROJECT I0N ON VERTICAL PLANE 67. - 247. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT 12000 67. STATE OF ALASKA AL~ .A OIL AND GAS CONSERVATION COMM!' N REPORT OF SUNDRY WELL OPERATI I N . 1. Operations performed: Operation shutdown __ Stimulate__ Plugging w Perforate ,/ Pull tubing ~ Alter casing __ Repair well ~ Pull tubing ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1030' F5L, 125' FWL, Sec.17, T10N, R15E, UH At top of productive interval .741' ~eLp~h2305' FEL, Sec.16, TION, R15E, UM At effective 653' FNL, 1956' FEL, Sec.16, TION, R15E, UM At total depth 645' FNL, 1924' FEL, Sec.16, TION, R15E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 74 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-32 9. Permit number/approval number 89-11/9-362 10. APl number 50-- 029-21910 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13500 ' MD feet feet 9222 'TVD 13455 ' MD feet 9191 'TVD feet Plugs (measured) Junk (measured) Plug f/1286'-1798' w/2400 sx CS II, & 1900 sx CS I None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 4400' 12762' 1019' 20" 13-3/8" 9-5/8" 7,7 2150# Poleset llO'MD 2500 sx CS III & 4434'MD 600 sx Class G - Top job w/120 sx CS II 500 sx Class G 12793'MD 350 sx Class G 12480'-13499'MD 110'TVD 3554'TVD 8708'TVD 8486'-9221'TVD measured trUe vertical 12992'-13033'MD, 13037'-13072'MD, 13076'-13111', 13116'-13126'MD, 13130'-13140'MD 8853'-8883'TVD, 8886'-8912'TVD, 8915'-8941'TVD 8945'-8952'TVD, 8955'-8962'TVD Tubing (size. grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tai 1 ~ 12540' Packers and SSSV (type and measured depth) CAMCO 'Bal-O' SSSV @ 2222', Baker 'FB-I' pkr @ 2423' 13. Still~lation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14' N/A 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. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~ ! Daily Report of Well Operations ~ Oil _~v Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 06~]5/88 Title Drilling Analyst (DAM) SW04/049 Date ~-10-~ SUBMIT IN DUPLICATE feet A?CO ALA>]KA; INC~ ANCHORAGE, ALASKA ,~,t,q DATE' ?-~ 8-89 REFEF(ENCE' ARCO F'F:E$$LJRE DATA S-.5 7-5-89 BHF ..... ,S"TA ]" t C GRADIEN]" CAMCO '~-'~...-.. .. -'-~-,qg; .~ ... BHF ....,?TA'r I E: GRADIENT CAMCO 3-'.2(') 6-i i-89 BHF ....FLOWING GRADIENT CAMCO 3-26 6-2i-89 BI-JP--F'I_Ot~ i N(~ GRAD i E,N"F CAMCO ,.:~'-- ::~ (c,. 6--. ~ °- 8 9= .Bi,IF ..... f:'i... 0 W i i'~ (; [; R A D I E N 1" CAHCO ,3-'~ ~ 7-6-89 BH~ ....;~]"A'T i C GRAD I EN T CAMCO 3-53 7-6-89 BHF ....Zi"AT i C GRADIENT CAMCO 3-34 6-i 3-89 BHF'--F'LOWING GRADIENT CAMCO 4-.4 7-8-89 BHF'--Sj]"AT I C GRAD I EN'T CAMCO 4-:5~ 6-~4-89 BHF'--ZTATIC GRADIENT CAHCO 7-34 6-3~-89 BHF'--STATIC GRADIENT. CAMCO i i-~ '= '7-~-89 BHF'--ZTATIC GRADIENT " CAMCO - 0 ii-4 7-F-~,9 BHF ....5*TATIC GRADIENT CAMCO t2-:32 6-t7-89 BHF'--5'TATIC GRADIENT CAMCO i 6-9 -'~'~ 6 ~-89 BHP--F'LOWZNG GRADIENT CAMCO t 7-~ 7-6-89 BIaF'--S'I'A'TIC GRADIENT CAMCO ~7-9 -7-8-89 BHP--STATIC GRADIENT - .... CAMCO_ PLEASE SIGN AND RETURN 'THE ATTACHED COPY AS RECEIPT OF DATA, DISTRIBUTION CENTR'~u"FILE£' CHEVRON EXTENSION? EXF'LORAT I ON EXXON,-, .... -: .... · ...~.~ - MARATHON.~. MOBIL PHILLIPS F'B WELL F'IL. ES' R &.b -.. BF'X STATE OF ALA&'KA TEXACO / D REiF:'EiRFNCEi* AF;:CO CA,~ED HOLE F:INAL..,.~' i - i 9 4 ..... l 4 .... 89 Z " C (", :.'.4.--'7 ,..~- ?-,..I ~' 3 .... t2 6'"i2 .... 89 4-'3' 4 .... t 4-89 ,a. .... ~ ,,."~' 6 -" t t -.. 1.3 9 4- 2 ¢ 6 .... 2-89 ,:~:_ ~ ":, . ., ,;. 6 - 3 '-' Iii 9 ..5- t ;F 4 '~ ,:...., ''~ ':';- 89 i ''~- 5 '- .... ~ 2- 3 '2 6 - t 4 "" 89 t4-t5 6 .... :3-89 t 4- ~,4 6-5-89 t 5 .... 4 6-4 .... 89 I '5 - t '5 6 - t -? - Iii 9 t6-7 4-28-89 t 8'"'23 .::,-5 i -89 C (:J L L.. A R /F:' E R F:' I N..J E C T I 0 N F' R 0 F' :1: L. E 'f .... : .: .... PIE R F' F,. E. L, :..J I'., D C 0 L.. 1.. A R /F:' Iii: R F" C 0 i... L. A R / P E. R F' I N J E C/" i 0 N F:' R 0 F I L E F:' I '1'2 C: 0 L L A R / PE R F ~ ', 5 A 5' L I F:' 1" ,.? J F', V E Y C. 0 L. L. ~ F,.: / F' E~ F;:. F: I iq. J E C T I 0 N F:' R 0 F:' I L. E INJEC'f'ION PROFII_E L. E A K I) E 1" E C: T I 0 N · ~ ~', '" · "t ,/ '% "' i" L;UI_LRI-,, I- L=RF: COL. i_~:~F,,/F E:.I',,F' F:' I T,S' I:,:UNt , 5" RUN t, 5" RUN t , 5" i:;,' U N ;~' i .-. :3, '.!~ ' F.,'t. JN t , '5" Ri.iN i , Ii.~" F;.'.UN i , ~" RUN t, '5" Rt.JN i , '.i>" I.;: Ut.,! "i ,~:" R U N t , '5" i-;,'UN t, 5" RUN t , t" RUN i , 5" F;.:UNi, 5" RUN t , 5" · ' i '1 ' i ..... · ' PI..EA,S'E ,S'IGN ~ND RE~I.IRN I'H.F AI'TACHED COPY AS' F,,Et.,E. IPI" (.iF DAI'A, HL..$ C A i'.'l C 0 I..I I... ;~.' A '1" I.. A ;.';' L: A M C 0 C ,:'.~ H C 0 I"1L.. 5' t:; A r,i L; 0 A'I i... ¢-':~ ;:; C A i',i C 0 C A M C 0 C A f'i C 0 A I I..A;~' I-'IL~' CA/'IC(] HAVE A NICE DAY! ZAL..LY I..IOF'Flii:CK!:i:R ~ JUl',,! 2 8 1,.989 ATO-I 529 'f'RAN5':~ 89263 Alaska Oil & Gas Cons. Commission Anchorage D 15' l'R I B U'lf' I 0 N CE:'NTRAL F I LES' CHEVRON D & M E:XTEN$ION EXF'LORAI'ION EXXON MARATHON MOBIL F:'H l LL I F'5'. . F'B WEI...L F'II.E. 5' R &'D .I. e · .. B X '"- ,S'I'A'I'E OF AL. AZKA "I' · ..'"' I'EXACO ARC..'.] AI...A..?I<A, INC,, F:' (), B 0 X i ,.':~ (') 3 6 (~ ANCI--IOF;:AC;E, AI..A,~'KA 9951 0 D A T E · 6- ~ 4-8 9 ~.<EF:E'F;.:I!i;NCE' ARCO CAS.'ED HOLE FINAL3' "fE;HPt[;AHH~ NEUTRON 'f'EHPi[;R '¥'Ei'4F'/6AHi'4A NEU"f'RON F'F'C ].' N J E C T I 0 N I::' R 0 F:' I L.. E C 0 M F' L E'f' I 0 N R E C 0 R D D I..I A I... B U R,.? T "1" D T- F:' F'I 1"5' · " ", .... If': I.. F,, U D ..I .., 'f' ]: 0 N P R 0 F I I.. E F;:UN t , 2 ......." ,*.,':~'", RUN t, 5" RLJN i , ...,':::" Rt..INt, '5" RUN t, 5:" RL.IN t , 5" RUN I, 5" RI...IN i, 5" RUN t , 5" I:'l...EA,":~'lii; ;.¢I6N AND RE'rUI:;:N 'f'l-~E AT'TACI-II:ZD "'F-, ~ t.,JI.."f' A;~' RECEIP'F OF DA'f'A I-'11... C. A H C 0 HL..~'..'.' A f' I... A ;}:,' C A M C: 0 · ;i;,' C H 3'CH C A H C C) C A H C 0 F,, E. C [:. I ¥ I.:.; D B Y I.-IAVE A NICIE DAY! ,.?ALLY H[)FF'ECKER ATO- t 529 C'EN I'RAI.. F'II..E,S' · "' ., I"1 I::. 'v R U N · ir J"" " ' ' ~" ' ~ EX'f'EN,S' T_ CINEXF'I...[)RAI" I ON 11" ~ EXXON MARAI'HI]N :l~ MOBIL · ,- F' H I L L I F' 5' F:'B WEL. L. F:']:L..E,.? Rag ~ BF'X .'~ S'TA'I"E OF ALA~'KA · "' TEXACO ALASKA OIL AN D GAS CONSERVATION COM MISSION'"' .... APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1030 FSL, 125'FWL, Sec. 17, TION, R15E, UM At top of productive interval 741'FNL, 2305'FEL, Sec. 16, TION, R15E, UM At effective depth 653'FNL, 1956'FEL, Sec, 16, TION, R15E, UM At total depth 645'FNL, 1924'FEL, Sec. 16, TION, R15E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 74 ' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 1~-32 @. Permit number 89-11 10. APl number 50-- 029-21910 11. Field/Pool Prudhoe Bay 0il Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Sudace 4400 ' Intermediate Production 12762 ' Liner 1019 ' Perforation depth: measured None 13500'MD 9222'TVD 13455 'MD 9191 'TVD Size 20" 1 3-3/8" 9-5/8" 7" feet feet feet feet Plugs (measured) Junk (measured) Plug f/1286'-1798' w/2400 sx CS II, & 1900 sx CS I None Cemented Measured depth True vertical depth 2150# Poleset 1lO'MD 110'TVD 2500 sx CS III & 4434'MD 3554'TVD 600 sx Class G - Top job w/120 sx CS II 500 sx Class G 12793'MD 8708'TVD 350 sx Class G 12480'-13499'MD 8486'-9221'TVD RECEIVED true vertical None MAY 1 0 1989 Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tai 1 e 1254/~~ll~f~ 0il & Gas Cons. Commiss/0r~ Anchorage Packers and SSSV (type and measured depth) Camco 'Bal-O' 555V @ 2222'~ Baker 'FB-I' pkr ~ 12423' 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation March 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ,/' Gas__ Suspended __ Service 17. I hereby certify t~t th~foregoing is true and correct to the best of my knowledge. Signed ,"'~,/~. ~ Title Regional Drilling Engineer FOR COMMISSION USE ONLY 070/,gA4 Conditions of approval: Notify C"ommission so representative may witness Plug integrity __ BOP Test __ Mechanical Integrity Test ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Date ~--1,,,~/~ Location clearance __ /~:~ Subsequent form required 10- ¢2 I Approval NO. ~,.. ~4¢ ~ I Ot~,;N!,r'i e ;.'.MITH Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday afte; a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. County. parish or borough NORTH SLOPE Lease or Unit Title ADL: 28331 COMPLETE State AK DS12-32 Well no. PRUDHOE BAY Auth. or W.O. no. AS2521 API: 50-029-21910 Operator ARCO ARCO W I Prior21 . 0000 Hour12:00 status if a W.O. Spudded or W.O. begun ACCEPT Date 03/14/89 Date and depth as of 8:00 a.m. O3/20/89 ( 3: TD:13500 PB:13454 SUPV:RO/LK 03/21/89 TD:13500 PB:13454 SUPV:RO/LK 03/22/89 ( 3: TD:13500 PB:13454 SUPV:RO/LK 03/23/89 ( 3~ TD:13500 PB:f3454 SUPV: K 03/24/89 ( 3! TD:13500 PB:13454 SUPV:GTG K Complete record for each day reposed AUDI RIG 4 RIH. W/ GR/JB 7"@13499' MW: 9.0 NaCl ACCEPT. RIG @ 0700 HRS, 3-19-89. ND TREE. NU BOPE'S. PULL BPV AND DUMMY HGR. SET TEST PLUG. TEST BOPE'S. TO 5000 PSI. HYDRIL TO 2500 PSI. TEST CSG TO 3000 PSI. RU ATLAS WL. RIH W/ 8.5" GR/JB TO 8534' COULD NOT GO DOWN. POOH. RECV'D RUBBER PIECES. RIH W/ 8.5" GR/JB TO 8534'. COULD NOT GO DOWN. POOH. RECV'D CMT CHUNKS. RIH W/ 8.35" GR/JB TO TOL AT 12,480'. POOH. RECV'D CMT CHUNKS. DAILY:S147,944 CUM:$2,879,914 ETD:S2,879,914 EFC:$2,676,000 DISP W/ 8.6 PPG SEAWATER 7"@13499' MW: 9.0 NaC1 FIN RUNNING GR/JB. RD ATLAS WL. CHNG OUT PIPE RAMS. INSTALL WB. MU 4-3/4" BHA AND RIH ON 3-1/2" DP. BREAK CIRC AT 500'. DISP W/ 9.0 BRINE. RIH W/ 3-1/2" DP. BREAK CIRC. PUMP HEC PILL (50 BBLS). DISPLACE OUT 9.0 PPG BRINE W/ 8.6 PPG SEAWATER TREATED W/ C-193. DAILY:S69,734 CUM:$2,949,648 ETD:$2,949,648 EFC:$2,676,000 RD ATLAS WIRELINE 7"@13499' MW: 8.5 NACL CIRC HEC PILL AND DISPLACE WELL W/INHIBITED SEAWATER. POOH, STANDING DP BACK. REPAIR VALVES IN CHOKE MANIFOLD. RU WESTERN ATLAS. RIH W/8.5" GR/JB TO 7595'. POOH, RECV'D CMT. RIH W/8.35" GR/JB TO 8550'. POOH, RECV'D CMT. RIH W/8.3" GR/JB TO 12480' POOH, RD ATLAS. DAILY:S42,737 CUM:$2,992,385 ETD:S2,992,385 EFC:$2,676,000 RIH W/8.35" GR/JB 7"@13499' MW: 8.5 NACL RD ATLAS. MU 8.5" MILL AND 9-5/8" CSG SCRPR ON DP AND RIH. WRK SCRPR ~ 7000' = 8000'. RIH TO TOL @ 12,477'. PUMP 100 BBL HEC PILL AND CIRC BTMS UP. POOH, LD BHA. RU ATLAS. RIH W/TANDEM 8.35" GR/JB TO 8560'. POOH, RECV'D SEVER~tL CUPS OF LARGE CMT CHUNKS. RIH W/8.35"/6.00" GR/JB TO TOL @12,480'. POOH, RECV'D TWO CUPS CMT. RIH W/8.35"/6.00" GR/JB. DAILY:S103,225 CUM:$3,095,610 ETD:S3,095,610 EFC:$2,676,000 TST 5-1/2" PIPE RAMS 7"@13499' MW: 8.5 NACL POOH, CLEAN CMT OUT OF JNK BSKT. RIH W/GR/JB TO 12440'. POOH, CLEAN CMT OUT OF JNK BSKT. RD ATLAS. MU BAKER 9-5/8" 'FB-i' PKR AND TAILPIPE AND RIH ON 3-1/2" DP. DROP BALL AND SET PKR ~ 12419' MD (RKB). SHEAR SETTING TOOL AND POOH, LD DP. WORK ON RIG SCR. CONT LD DP. PULL WEAR RING AND INSTALL 5-1/2" RAMS AND TST SAME TO 5000 PSI. DAILY:S54,124 CUM:$3,149,734 ETD:S3,149,734 EFC:$2,676,000 sFe°er '~mcePdruerPeaLal~lia°rnuaa~,%edi¢llr~nbufi0,°n' /~./ ~ Drilling, Pages 86 and 87. ~ AR3B-459-1-D _hr!rang_ Supt. (-~(~in~l~'tJhll"~aily well history forms consecutively ~O~e~ ]h~ they are prepared f ..... h well. Page no. ARCO Oil and Gas Company {~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pertormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lelertm;' sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled oul bul not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of od string until completion. District Field ARCO ALASKA INC. County or Parish JState NORTH SLOPE AK JLease or Unit DS12-32 PRUDHOE BAY Date and depth as of 8:00 a.m. 03/25/89 ( TD:13500 PB:13454 SUPV:GTG K 03/26/89 ( TD:13500 PB:13454 SUPV:GTG K Complete record for each day while drilling or workover in progress AUDI RIG 4 Well no. RIH W/5-1/2" TUBING 7"@13499' MW: 8.5 NACL MU BAKER SEAL ASSEMBLY ON 5-1/2" MOD BTC CL 'A' TUBING AND RIH. SPACE OUT 8 GLM'S IN THE STRING. (CAMCO 'BAL-O' SSSV @ 2222', BAKER 'FB-i' PKR @ 2423', & TT @ 12540) DAILY:S25,050 CUM:$3,174,784 ETD:S3,174,784 EFC:$2,676,000 RIG DOWN, PREP TO MOVE 7"@13499' MW: 8.5 NACL RIH W/COMP ASS'Y. STING INTO PKR AND PRESS TBG TO 500 PSI. SPACE OUT AND MU MCEVOY GEN IV TBG HNGR. MU CNTRL LINES AND TST TO 5000 PSI. FREEZE PROTECT TOP 2200' OF WELL W/DIESEL. LND HNGR AND PRESS TBG TO 2850 PSI. BALL SHEARED IN PKR TAIL. PRESS TBG TO 3000 PSI F/30 MIN. PRESS TST ANN TO 3000 PSI F/30 MIN. BACK OUT LNDNG JT, THREADS GALLED. ?U AND LD TBG HNGR. RECUT 6-1/8" LH ACME LANDING THREADS IN HNGR AND RE-LAND HNGR AND RETEST. RETEST TBG AND ANN TO 3000 PSI. LD LNDNG JT AND SET BPV. INJECT 460 BBLS JUNK FLUID DOWN 9-5/8" X 13-3/8" ANN. ND BOP'S, NU MCEVOY TREE AND TST TO 5000 PSI RIG DOWN RIG AND WAIT ON WEATHER. DAILY:S290,194 CUM:$3,464,978 ETD:S3,464,978 EFC:$2,676,000 · , , The abovei ....... t) Sign ure For form p~'ep~a[T'~n and di~tribuUo~'~/ see Procedures Manual Section 10/'/ Drilling, Pages 86 and 87 Ti'leo ~ C ~~~pt. · AR3B-459-2-B INumber all daily well history forms consecutively fP,iq(! rio as they are prepared lot each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after a!lowable has been assigned or wail is Pluoged, Abandoned. or Sold "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time On w~)rkovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporting the entire operation if space is a,va,lable. [ Accounting cost center code District County or Parish IState / / AN .~3.CO ALASKA INC. Field Auth. or W.O.~n~ ...... AE2521 Lease or Unit ADL: 28331 Title COMPLETE DS!2-32 Jwel, no. Operator Spudded or W~.'~eOgun ACCEPT Date and depth as of 8:00 a.m. 03/27/89 ( 3 TD:13500 PB:13454 SUPV:GTG K API' 50-029-21 9'it0 ARCo. W.I. ,Total number of wells (active or inactive) on this Icost center prior to plugging and 21. 0000 Jabandonmem of this welt Date ,Hour Prior status if a W.O. / Complete record for each day reported AUDI RIG 4 ) WAIT ON WEATHER 7"@13499' MW: 8.5 NACL WAIT ON WEATHER TO FINISH RIGGING DOWN. RELEASE RIG @ 0930 HRS 03/26/89. WAIT ON WEATHER TO MOVE. DAILY:S123,549 CUM:$3,588,527 ETD:S3,588,527 EFC:$2,676,000 Old TD I New TD PB Depth Released rig I Date K nd of r g Classifications (oil, gas, etc.) Type completion (single, dual. etc.) Producing method Official reservo r name(s) Potential test data Well no. Date Reservoir Producing Intervat Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The ab°va is t~;~'~ect ) / ' / Date// ,Title Drilling, Pages 86 and 87. MAY 0 19 9 A~SkA 0~ & Gas Cor~o. Num~i~ history f ........... tlvely Pag .... AR38-459-3-C as th%~-are prepared for each well, DIvlNon of AtlantlcR~lchfleldCompany ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "initial Report" On the first Wednesday after a well is spudded or workover operations are started. Daily work prior tO spudding should be summarized on the form giving inclusive dates only. District JCounty. parish or borough I Field Alice ALASKA INC. JLease or~J~ Auth. or W.0.Fr~UuHr~l': t'",AX jTitle AuL: 28331 I AS2521 State ~ Well no. DS 12-32 Operator Spudded or W.O. begun AL-'i: 50-029-21910 ARCO W l IDate IHour Pr,or status if a W.O. 21.0000 ARCO Date and depth as of 8:00 a.q~puD 02/15/89 ( TD: 110' ( SUPV: JH 02/16/89 ( TD: 494'( SUPV:JH 02/17/89 ( TD: 1250'( SUPV:JP/JR 02/18/89 ( TD: 1530'( SUPV:JP/JR 02/19/89 ( TD: 1798'( SUPV:JP/JR 02/20/89 ( TD: 1286'( SUPV:JP/JR 02/21/89 ( TD: 1850' ( _er3p~r · ._-~_/._'r~__ The above is correct Complete record for each day reported 02/15/89 1030 HRS ,) ,lO) :) ,84) ,) 56) ) :80) For form preparation a~d~di~tributi~nn, see Procedures Manu~l,~ection 10, Drilling, Pages 86 AR3B-459-1-D ~) ~.68) ;) o) ) ~64) NABORS 28E MIXING SPUD MUD 20"@ 110' MW: 9.0 VIS: MOVE RIG F/ DS 12-33 TO DS 12-32. NU DIVERTER, ACCEPT RIG @ 0330 HRS 2/15/89. FILLED PITS AND MIXING SPUD MUD. DAILY:S42,400 CUM:$42,400 ETD:S42,400 EFC:$2,676,000 DRILLING 20"@ 110' MW: 9.0 VIS:232 PU BHA. FUNCTION TEST DIVERTER SYSTEM. SPUD WELL @ 1030 HRS, 2/15/89. DRILL TO 333'. ROTARY CHAIN BROKE, POOH, REPAIR CHAIN, RIH. DRILL TO 394'. UNPLUG FLOWLINE. DRILL TO 484'. POOH, MU NEW BHA, RIH. ATTEMPT TO DRILL. FLOWLINE PLUGGING OFF W/ BOTH PUMPS ON LINE. POOH, LD F2000S MOTOR, PU D-500 MOTOR, RIH. ATTEMPT TO DRILL, MOTOR STALLING OUT. DAILY:S85,457 CUM:$127,857 ETD:S127,857 EFC:$2,676,000 DRILLING 20"@ 110' MW: 9.1 VIS:205 DRILL TO 524'. POOH, CHANGE DYNA DRILL, RIH. DRILL TO 976'. POOH FOR BIT, RIH. DRILL TO 1250'. DAILY:S44,407 CUM:$172,264 ETD:S172,264 EFC:$2,676,000 DRILLING 20"@ 110' MW: 9.2 VIS:208 DRILL TO 1309'. POOH, CHANGE OUT MOTOR, RIH. DRILL TO 1319'. ATTEMPT MWD SURVEY, MWD FAILED. POOH, CHANGE MWD, RIH. REAM TO BOTTOM, BOULDER ON BOTTOM. DRILL TO 1410'. UNPLUG FLOWLINE OF WOOD & COAL. DRILL TO 1530'. DAILY:S54,309 CUM:$226,573 ETD:S226,573 EFC:$2,676,000 WOC 20"@ 110' MW: 9.1 VIS:212 DROP SURVEY & PUMP SLUG. POOH FOR BHA (ANGLE DROPPING TOO MUCH). PU NEW BHA & RIH. DRILL TO 1632', ANGLE DROPPING. SURVEY, SLUG & POOH. PU BHA & RIH. DRILL TO 1798', ANGLE DROPPING. POOH & LD BHA. RIH OPEN ENDED. CIRC & RU BJ PUMP 2400 SX CS II @ 14.9 PPG, SET BALANCE PLUG F/ 1798'-1000'. POOH & LD DRILL PIPE. WOC. DAILY:S181,143 CUM:$407,716 ETD:S407,716 EFC:$2,676,000 WOC 20"8 110' MW: 9.1 VIS:210 WOC. RIH TO 1297', NO CMT. CBU, 5 BBLS GREEN CMT. RIH TO 1436', TAGGED HARD CMT. CBU. POOH & LD BHA. RIH OPEN ENDED. CIRC & WOC. RU BJ, PUMP 1900 SX CS I @ 15.2 PPG, SPOT PLUG F/ 1436'-845'. POOH, LD DRILL PIPE. WOC. DAILY:S74,474 CUM:$482,190 ETD:S482,190 EFC:$2,676,000 DRILLING W/ DYNA DRILL 20"@ 110' MW: 9.4 VIS:205 WOC. RIH, TAG CMT @ 1286'. C&C. POOH. RIH W/ MOTOR & 3 1850'. ate Title DAILY:$68,1~ CUM:$550,35~ ETD:S550,352 EFC:$2,676,000 MAY 1 o 1989 INumber all daily well history forms consecutively a the ar ; ~ o~.~ well. Anchorage Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations If testing, coring, or perforating, show formation name in describing work performed. Number ali drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less Irequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oll siring until completion. District Field ARCO ALASKA INC. PRUDHOE BAY Date and depth as of 8:00 a.m. C°un" °'"9;$H SLOP~. S'a',tK L ...... ~n~tl 2_32 It,Nell no 02/22/89 ( TD: 2250' ( SUPV: JP /JR 02/23/89 ( TD: 3733'( SUPV:JH/RB 02/24/89 ( TD: 4450'( SUPV:JH/RB 02/25/89 ( TD: 4450'( SUPV:JH/RB 02/26/89 ( TD: 4450'( SUPV:JH/RB 02/27/89 ( TD: 5238'( SUPV:JH/RB Complete record~BORSf r each daY2while8E drilling or workover in progress 3) Ioo) 483) 0) 717) 1) o) 2) 0) 3) 788) PU NEW BHA 20"@ 110' MW: 9.4 VIS:143 DRILL TO 2043'. SURVEY, SLUG, POOH. CHANGE BHA. RIH, SLIP & CUT, RIH. C&C. WASH & REAM TIGHT SPOT F/ 1872'-2043'. DRILL TO 2250' , COULD NOT SLIDE MOTOR. POOH & PU BUILDING ASSEMBLY. DAILY:S60,263 CUM:$610,615 ETD:S610,615 EFC:$2,676,000 DRILLING 20"@ 110' MW: 9.7 VIS:146 RIH. REAM F/ 1963'-2250'. DRILL TO 2548' POOH }{AD TO PUMP OUT TO 2122'. CHANGE BHA, RIH. REAM F/ 2250'-2548'. DRILL TO 3004'. W/L SURVEY, MWD FAILED. DRILL TO 3439'. HOLE TIGHT, CIRC HI-VIS PILL. DRILL TO 3733' DAILY:S62,268 CUM:$672,883 ETD:S672,883 EFC:$2,676,000 CIRC BOTTOMS UP 20"@ 110' MW:10.0 VIS:120 DRILL TO 3966'. CIRC, DROP SS, SLUG. POOH TO 2500', PUMP OUT OF HOLE F/2500' -1898', FIN POOH. CHANGE BHA, RIH TO 1271'. REPAIR HYDRAULIC SYSTEM ON RIG. RIH TO 1970', HOLE TIGHT, WASH TO 3633'. DRILL TO 4450'. CBU. DAILY:S54,509 CUM:$727,392 ETD:S727,392 EFC:$2,676,000 WELDING ON CASINGHEAD 13.325"@ 4434' MW:10.0 VIS: 97 SHORT TRIP, TIGHT @ 2530'. C&C. POOH, NO TIGHT SPOTS. RU CSG TOOLS. RAN 111 JTS 13-3/8", 689, L-80, BTC. RAN 2 JTS, 13-3/8", 68#, K-55, BTC ON TOP. CIRC 700 BBLS & RECIP PIPE. PUMP 100 BBLS FRESH H20 SPACER. MIX & PUMP 2500 SX CS III @ 12.2 PPG + 600 SX CLASS 'G' @ 15.8 PPG. BUMP PLUG W/ 2500 PSI, FLOATS HELD. PERFORMED 120 SX TOP JOB W/ CS II @ 14.7 PPG. ND DIVERTER, SET SLIPS, CUT PIPE, WELD ON CASING HEAD. DAILY:S218,804 CUM:$946,196 ETD:S946,196 EFC:$2,676,000 WOW 13.325"@ 4434' MW: 0.0 VIS: FIN WELDING ON CSG HEAD, TEST TO 500 PSI W/ N2 WHILE HOT, 1500 PSI W/ N2 AFTER COOLING. NU DRILLING SPOOL & BOPS.' TEST BOPS. WOW. DAILY:S216,157 CUM:$1,162,353 ETD:S116,353 EFC:$3,722,000 DRILLING 13.325"@ 4434' MW: 8.9 VIS: 36 WOW. PU 12-1/4" BHA & RIH. TEST CSG TO 2500 PSI. DISPLACE MUD W/ GEL WATER. DRILL CMT & FLOAT COLLAR. TEST CASING TO 2500 PSI. DRILL CMT, FLOAT SHOE & 10' NEW HOLE. PERFORM LOT TO 12.8 PPG EMW. DRILL & SLIDE TO 5238'. DAILY:S49,315 CUM:$1,211,668 ETD:S1,211,668 EFC:$2,676,000 T~e abov],i,s ...... h ,r' For form preparation and distribution see Procedures Manual Section 10,2~// Drilling, Pages 86 and 87 // AR3B-459-2-B ~,,~~ IT't'e Drilling Supt. RECEIVEP MAY 1 0 Co,u h~qlSo~ul., Alaska Oil & Gas Con'_',," Am;h0rag¢ INumber all daily welt h~story forms consecutively as they are prepared for each well. Page no ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing1 coring, or perforating, show formation name in describing work performed. Number a;I drill stem tests sequentially, Attach description of ail cores Work performed by Producing Section will be reported on "Interim" shee~s unlil final completion. Report official or representative test on "Final" form. 11 Submit "Interim" sheets when filled oul but not less frequently than every 30 days1 or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of od strin~ un comp el on District ICounty or Parish IStat,~K ARCO ALASKA INC. I NORTH SLOPE Field ~Lease or Unit PRUDHOE BAY J DS12-32 Complete record for each day while drilling or workover in progress NABORS 28E Date and depth as of 8:00 a.m. 02/28/89 ( TD: 6691'( SUPV:JH/RB 03/01/89 ( TD: 7527'( SUPV:JH/RB 03/02/89 ( TD: 8087'( SUPV:JP/RB 03/03/89 ( TD: 8965'( SUPV:JP/RB 03/04/89 ( TD: 9815'( SUPV:JP/RB 03/05/89 ( TD:10557'( SUPV:JP/RB 03/06/89 ( TD:11697'( SUPV:JP/RB 03/07/89 ( TD:11829'( SUPV:JP/RB IWeH no ~) ~53) 5) 836) 6) 60) 7) B78) 3) 850) 9) 742) 9) 140) 1) 132) POOH 13.325"@ 4434' MW: 9.3 VIS: 33 DRILL & SLIDE TO 6050' SHAKER SCREENS BLINDED W/ SAND, REPLACE SCREENS. DRILL TO 6691'. DAILY:S52,793 CUM:$1,264,461 ETD:S1,255,461 EFC:$2,685,000 RIH 13.325"@ 4434' MW: 9.4 VIS: 40 DRILL TO 6691' POOH, PU NEW BIT, RIH. SLIP & CUT. FIN RIH, HIGH WINDS SLOWED TRIP IN. DRILL TO 7527'. POOH, LD MOTOR. PU NEW BHA & RIH. DAILY:S52,281 CUM:$1,316,742 ETD:S1,316,742 EFC:$2,676,000 RIH 13.325"@ 4434' MW: 9.5 VIS: 54 FIN RIH. DRILL TO 8073'. CIRC WHILE REPAIRING PUMP #1. DRILL TO 8087'. DROP SURVEY, SLUG, POOH. CHANGE BIT & MWD. RIH. DAILY:S54,932 CUM:$1,371,674 ETD:S1,371,674 EFC:$2,676,000 RIH 13.325"@ 4434' MW: 9.6 VIS: 56 DRILLED TO 8391'. CIRC WHILE ATTEMPTING MWD SURVEY, MWD FAILED. RAN WIRELINE SURVEY. DRILLED TO 8894'. PUMPED DOWN WIRELINE SURVEY. DRILLED TO 8965'. SLUG & POOH. SLIP & CUT. RIH W/ NEW BIT & MWD TOOL. DAILY:S53,950 CUM:$1,425,624 ETD:S1,425,624 EFC:$2,676,000 DRILLING 13.325"8 4434' MW: 9.6 VIS: 52 DRILLED TO 9777'. ATTEMPT MWD SURVEY, SURFACE EQUIP FAILED. DROP SS SURVEY. SLUG, POOH, PU NEW BHA, RIH. DRILL TO 9815'. DAILY:S56,906 CUM:$1,482,530 ETD:S1,482,530 EFC:$2,676,000 RIH 13.325"@ 4434' MW: 9.6 VIS: 49 DRILLED TO 10557'. DROP SURVEY, SLUG, POOH. PU NEW BHA, SLIP & CUT, RIH. DAILY:S49,102 CUM:$1,531,632 ETD:S1,531,632 EFC:$2,676,000 POOH 13.325"@ 4434' MW:10.0 VIS: 46 DRILLED TO 11697'. DROP SURVEY, SLUG, POOH FOR BHA. DAILY:S78,573 CUM:$1,610,205 ETD:S1,610,205 EFC:$2,676,000 RIH 13.325"@ 4434' MW:10.3 VIS: 52 FIN POOH, CHANGE BHA, RIH. DRILL TO 11829', BIT QUIT DRLG. ATTEMPT MWD SURVEY. DROP SS, PUMP SLUG, POOH FOR BIT & MW/). RIH, SLIP & CUT, RIH. DAILY:S64,062 CUM:$1,674,267 ETD:S1,674,267 EFC:$2,676,000 Drilling, Pages 86 and 87' U IDate / ITitle 1_7/,~3~ ? Drilling Supt. RECEIVE[:: MAY 1 o AR3B-459-2-B Alaska, 0il & Gas oo~;. C;ommis~;'oi~ Anchorage, INumber all daily well hislory forms consecutively as they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim · Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name ~n describing work performed. Number all drill stem tests sequentially. Attach description of alt cores Work performed by Producing Section will be reported on "Interim" sheets unlil final completion Report official or representative test on "Final" form, t) Submit "lnlerim" sheets when filled out but not less frequendy than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and fei owing setting of oil string until completion. District ARCO ALASKA INC. [County or~6r~s~H SLOPE · Lease or ~n~l2 Field PRUDHOE BAY -32 Date and depth Complet ...... d ~)~aY2w~e drilling ..... k .... in prog .... as of 8:~ a,m, 03/08/89 (22) TD: 12565' ( 736) SUPV:~/RB 03/09/89 (23) TD: 12810' ( ~45) SUPV: ~H 03/10/89 ( TD: 12810' ( 0) SUPV: ~H 03/11/89 ( 5) TD: 13147' ( 337) TD: ~3~00' { 253) 03/13/89 (7) TD: 13500' ( 100) SUPV: ~H The above is~rrect ~ -- Drilling, Pages 86 and 87 // ' staleAK 77OII no DRILLING 13.325"@ 4434' MW:10.4 VIS: 48 DRILL TO 11968'. CIRC WHILE REPAIRING ROTARY DRIVE CHAIN. DRILL TO 12470'. MWD SURVEY. DRILL TO 12565' DAILY:S62,602 CUM:$1,736,869 ETD:S1,736,869 EFC:$2,676,000 POOH TO RUN CSG 13.325"@ 4434' MW:10.6 VIS: 51 DRILLED TO 12800'. MWD SURVEY. SHORT TRIP. DRILLED TO 12810'. C&C, DROP SINGLE SHOT SURVEY. POOH, TIGHT SPOT 10758', WORK PIPE, RIH. CIRC & RAISE MUD WT TO 10.6 PPG. POOH. DAILY:S48,144 CUM:$1,785,013 ETD:S1,785,013 EFC:$2,676,000 RD CSG TOOLS 9-5/8"@12793' MW:10.6 VIS: 53 FIN POOH & LD BHA. CHG TOP RAMS TO CSG RAMS & TEST BONNET SEALS. PULL WEAR BUSHING & RU CSG TOOLS. RAN 155 JTS 9-5/8", 47#, L-80, BTC AND 142 JTS 9-5/8" 47#, L-80, BTC MOD. SET SHOE AT 12793'. CIRC 2 CSG VOLUMES & RU BJ TITAN. BATCH MIX 500 SX CL 'G' GAS BLOCK @ 15.8 PPG. BUMP PLUG W/ 3000 PSI, FLOATS HELD. RD CSG TOOLS. DAILY:S347,442 CUM:$2,132,455 ETD:S2,132,455 EFC:$2,676,000 DRILLING 9-5/8"@12793' MW: 9.0 VIS: 40 LD LDG JT. CHANGE TOP RAMS TO 5", TEST BOPS. INSTALL WEAR BUSHING. LD 12.25 BHA, PU 8.5" BRA. SLIP & CUT. RIH, TAGGED CMT @ 12691'. TEST CSG TO 3000 PSI. DRILL FLOAT COLLAR & CMT TO SHOE. ATTEMPT TO RETEST CSG, FLOAT SHOE WOULD NOT HOLD. DRILL SHOE & 10'. C&C, PERFORM LOT TO 12.5 PPG EMW. DRILL TO 13147'. DAILY:S118,751 CUM:$2,251,206 ETD:S2,251,206 EFC:$2,676,000 LOGGING 9-5/8"@12793' MW: 9.0 VIS: 37 DRILLED TO 13152'. DROP SS, PUMP SLUG, POOH FOR BIT. RIH. DRILLED TO 13400'. CBU, POOH. RU ATLAS WIRELINE, RUN GR/DIL/AL/DIEL F/ 13400' TO 12794' DAILY:S66,766 CUM:$2,317,972 ETD:S2,317,972 EFC:$2,676,000 RIH W/ 7" LINER 9-5/8"612793' MW: 9.0 VIS: 39 FIN LOG RUN #1. RUN GR/CNL/ZDEN/ML/CAL F/ 13400' - 12779'. RD ATLAS E-LINE. RIH W/ 8-1/2" BIT. DRILLED TO 13500' FOR ADDITIONAL RATHOLE. C&C. POOH. RU CSG TOOLS. RUN 25 JTS 7", 29#, L-80, BTC CSG. PU BDT LINER HGR. CIRC CAP OF CSG. RUN LINER IN ON DP. SLIP & CUT. CONTINUE TO RIH W/ LINER. DAILY:S168,066 CUM:$2,486,038 ETD:S2,486,022 EFC:$2,676,016 Drilling Supt, RECE!Vrr'?, AR3B-459-2-B Alaska 0il &" Number all ~1 ~y forms consecutively as they are prepared for each well, Page no ARCO Oil and Gas Company,~,,'~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations If testing, corinG, or perforating, show Iormation name in describlng work performed. Number aH drHI stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1~ Submit "interim" sheets when filled out but not less frequently than every 30 days, or (2) on WednesDay of the week in which oil string is set. Submit weekly for workovers and following SettinG of oH strinG unlil completion. District ]County or Parish ]StateAK ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit PRUDHOE BAY DS12-32 Complete record for each day yvbile drilling or workover in progress NABORS 28E Date and deptiq as of 8:00 a.m. 03/14/89 ( TD:13500 PB: SUPV:JLH 03/15/89 ( TD:13500 PB:13454 SUPV:JLH IWell no. LD 8-1/2" BHA 7"@13499' MW: 9.0 WBM FIN RIH W/ 7" LINER TO 13499'. CBU. BATCH MIX 350 SX CL 'G' GAS BLOCK CMT @ 15.7 PPG. PUMP 50 BBL MCS-A SPACER FOLLOWED BY CMT. DROP LINER DART, DISPL CMT. BUMP PLUG & SET LINER HGR W/ 3500 PSI. RELEASED F/ HGR & POOH. LD RNG TOOLS. RIH W/ 8-1/2" BIT, TAG CMT @ 12226'. DRILL RATTY CMT F/12226'-12380'. DRILL FIRM CMT F/ 12380' TO TOL @ 12480'. CIRC HOLE CLEAN. POOH & LD 8-1/2" BHA. DAILY:S123,193 CUM:$2,609,231 ETD:S2,609,231 EFC:$2,676,000 LD DRILL PIPE 7"@13499' MW: 9.0 NACL PU 6" BIT & BHA, RIM TO TOL. CLEANED OUT LINER TO LDG COLLAR. TEST CSG TO 3000 PSI. DRILLED LDG COLLAR & CMT TO FLOAT COLLAR @ 13454'. TEST LINER TO 3000 PSI. CBU, REVERSE CIRC 300 BBLS FRESH WTR, 50 BBL HI-VIS PILL, AND REVERSE HOLE TO 9.0 PPG NACL TREATED W/ C-193. TEST CASING TO 3000 PSI. POOH AND LAY DOWN DRILL PIPE. DAILY:S79,939 CUM:$2,689,170 ETD:S2,689,170 EFC:$2,676,000 AR38-459-2-B Dfllllng Supt. RECEIV MAY 1 0 Alaska Oil & ~--," ," Number all t~a'l]~lT%l~'~r~ forms consecutively as Ihey are prepared for each well. [P;~c~c no ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after al!owable has been assigned or wed ,s P!uqged, Abandoned, or Sold "Final Report" should be submitted also when operations are suspended for an indefinite Or appreciable length of time On ~'orkovers wh,~.n ,'~n offi(.-i,~l [est is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporhng lhe enhre operation if space is avadab~e. District County or Parish ARCO ALAS['~. INC. Lease NORTH SLOPE Field or Unit PRUDHOE BAY ADL: 28331 Auth. or W.O. no. T t e AS2521 DRILL ]Acco~Jnting cost center code St;de AK DS 12-32 lweu no API: 50-029-21910 Operator Spudded or Date and dep~PUD as of 8:00 a.m. 03/16/89 TD:13500 PB:13455 SUPV:JLH A.R.Co. W.I, Date 21.0000 Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our Prior status if a W.O. Complete record for each day reported 02/15/89 1030 HRS NABORS 28E RIG RELEASED 7"@13499' MW: 9.0 NaCl FIN LD DRILL PIPE. FREEZE PROTECT TOP 400' W/ DIESEL. ND BOPS, NU TBG HEAD, DUMMY HGR & DRY HOLE TREE. TEST TO 5000 PSI. FREEZE PROTECT 13-3/8" X 9-5/8" ANNULUS ON WELLS 12-32 & 12-30. RELEASE RIG @ 1700 HRS 3/15/89. DAILY:S42,800 CUM:$2,731,970 ETD:S2,731,970 EFC:$2,676,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method New TD Date PB Depth Kind of rig Type completion (single, dual, etc,) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Fo.r lot~ preparation an, d dis?ibu~/ ~er~l I iPn~ c ~da~ ~%s 8M6 aannU: 18 7S' e c t ' ° n ~ R AR3B-459-3-C Number all daily well history forms consecutively I Page no. las they are prepared for each well. I AiaSg Oil & ' Dlvl~on of AtlanflcRIchfieldCompany F',O, BOX t0¢360 ~"' ANCHORAGE, AI_ASKA 995. 3 DATE' 3-29-89 REF'E:RENCE: ARCO MAGNETIC TAPE(S) WITH LISTING(S) t~-~'~ ~ 3-t2-89 OH: DIF'L/BHC/DIEL/MINI/CZD/CNL JOB~3749 "1 " t.* * · " F I...EASE SIGN AND RETURN THE ATIA£,HED COF'Y AS RE[;EIF'T OF' DATA, ATLAS' RECEIVED BY HAVE A NICE DAY! SAL. LY HOFFECKER ATO- i DISTRIBUTION CENTRAL FILES (CH) CHEVRON D & M TAMMA$ BROWN (OH). EXXON MARATHON MOBIL P F' HILLI F'B WELL. FILES SAF'C STATE OF ALASKA TEXACO ARCO ALASKA, INC. F'.O. BOX tO0~&O ANCHORAGE, ALASKA DATE · REFERENCE: 4-4-89 ARCO CASED HOLE FINALS i-9 3-t~-89 LEAK DETECTION 2-~7 3-22-89 TEMF' & GAMMA TIE-IN 5-t3 3-t2-87 LEAK DETECTION 6-~2 3-25-89 COLLAR/F'ERF 6-t4 3-~8-89 COLLAR/PERF 7-~4 3-~2-89 LEAK DETECTION 9-~6 3-27-89 TUBING CUTTER ~-24 3-~5-89 TEMP tt-24 3-t9-89 COLLAR/PERF t2-32 3-t6-89 CBT ,~.t2-32 3-t6-89 CET t5-8 3-i3-89 PIT/PRODUCTION ~5-25 3-1t-89 PRODUCTION PROFILE t8-t4 3-~?-89 PERF RECORD ~ 8-~ 5 3-t 7-89 PRODUCTION ~8-~5 3-~8-89 DUAL BURST 'FDT-P t8-20 3-26-89 COLLAR/PERF RUN RUNS ~&2, 2'&5' RUN t, 2'&5' RUN t, RUN t, 5' RUN t, 2'&5' RUN RUN i, 5' RUN t, 5' RUN t, 5" R!~N RUN RUN RUN RUN RUN RUN ~, 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY___ HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRAN$ -~8~ t~7 AF'F'ROVED .~ DISTRIBUTION CENTRAL FILE~'' CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON 5. MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO CAMCO OTIS CAMCO Al'LAS A'i' LA~' CAMCO ATL. A3' CAMCO ATLAS SCH $CH ~'CI--! CAMCO ;~'CI'-t $CH $CH ATLA3~ ARCO ALASKA, INC~ F'~O~ BOX i00,360 ANCHORAGE, ALASKA 995i0 REFERENCE ' ARCO OPEN HOLE FINALS 2-32 3-t 2-89 2-3"2 3-t 2-89 i2-32 [~-i 2-'89 2'-32 3-' i 2-89 2-32 Z~'-i 2-89 ~2-32 3-t 2-89 BHCA-GAMMA DIF'L-GAHMA CZD--GAMHA (RAW) CZD/CNL-GAMMA (PORO) D I ELECI'R I C-GAMHA MINILO6'-GAMMA RUN RUN i, 2"&5" RUN i, RUN i , RUN i RUN i , 5" F[.E.A~S[:. ,';IGN AND RETURN Tt-tE ATTACHED COF'Y AX RECEIPT JIF' DAI"A~ A"I"L. AS ATt_A£' AI'L.A,S' ATI_AS A"I'L. AS AI'I..A$ RECEIVED ~Y ............................................... HAVE A NICE DAY! EC IV AT0-i529 ~--' -~x~ 2 [~ . . ~ Alaska Oit & Gas Con~. Gomm~smon 'FRANS ,89i_~ Anchorage APPROVED ..... DISTRIBUTION · "~ CENTRAL FILES ~' PHILLIPS ~ CHEVRON F'B WELl.. I::'I[..ES ~~ D & M ..- ~' R & D '"'.,r EXTENSION EXPL. ORATION -,.'"' SAF'C ~ EXXON ~'"- STATE OF ALASKA ,~ MARATHON '" TEXACO ~' MOBIL January 27, 1989 Telecopy~ (907)276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: P~dhoe BaY Unit DS 12-32 ARCO AlaSka, In¢' Permit No. 89-11 Sur. Loc. 1030'FSL, 125'FWL, Sec. 17, T10N, R15E, UM. Btmhole Loc. 729'FNL, 1961'FEL, Sec. 16, T10N, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this'office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly yo~s, ~~ ~hat~erton ..x / Chai~an of Alaska Oil and Gas Conservation Co~isston BY ORDER OF THE COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA _ .L AND GAS CONSERVATION CL.,~MISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill [] Redrill []l lb. Type of well. Exploratory [] Stratigraphic Test El Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 74'. PAD 41'GL feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oil Pool P.O. Box 100360, Anchorage, AK 99510-0360 ADL 283:31 4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee 2o AAC 25.O25) 1030'FSL, 125'FWL,Sec.17,T10N,R15E,UM Prudhoe Bay Uni~ Statewide At top of productive interval ((~ 8914 ' TVD ) 8. Well nu .mber Number 825'FNL, 2200'FEL,Sec.16,T10N,R15E,UM DS 12-32 #8088-26-27 At total depth 9. Approximate spud date Amount 729'FNL, 1961 'FEL,Sec.16,T10N,R15E,UM 02/10/89 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 12-27 54' 13309'MD 729' (~ TD feet ~ 818'MD/816'TVD feet 2560 9119'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 500 ' feet Maximum hole angle51 0 Maximum surface psig At total depth (TVD) psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110' ?OHO# 17-1/2" 13-3/8" 68# iK-55 BTC 20' 30' 30'. ,5( ' .50' 2500 sx CS Ill & 72# L-80 BTC 4409' 50' 50'i 445c. ' 3500' 600 sx Class 12-1/4" 9-5/8" 47# L-80 BTC/Mod 12601' 30' 30'i 12631' 8689' 500 sx Class G 8-1/2" 7" 29# L-80 BTC 978' 12331' 8498' 1330c,' 9119' 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°r~da;;TM RECEIVED Intermediate ProductionJAN 1 8 _. Liner ~$~f,~ ¢il & Gas Cons. ¢0mr~sl0n Perforation depth: measured ..... ~,~i;'.~llchoral]t]i , true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ DiverterSketch ~ Drilling program L~ Drilling fluid program [] Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby certify that~th,e fo~regoing is true and correct to the best of my knowledg~ Signed "~,/'~~~'/'"' Title Regional Drillinn Fnnin~.~r Date¢/~,/~ ~/' Commission Use Only ~42,~'/,/ (GSW) PD3/056 g~..// 50- g.2_., ':) - ~ / '~ / O 01 / 2 7 / 89 for other requirements Conditions of approval Samples required [] Yes ,~ No Mud log required _F-] Yes ,,~ No Hydrogen sulfide measures [] Yes ,,~No Directional survey required ~ Yes [] No Required workingpre~surefo~BOPE/,,.4~M; E3 3Ms j~ 5Ms [] 10Ms [] 15M Other://,~...~/~ ! ,. ~-/'~~ ~ by order of Approved by t - ...// Commissioner the commission Date Form 10-401 Rev. 12-1-85 Subr; PBU DS 12-32 OPERATIONS SUMMARY (PRODUCER) 1. MIRU drilling rig. 2. Spud well and drill 17-1/2" hole to 500'and kick off. Build angle at 2.5°/100' to 50'-' 34' at N 67-o 25' E. Drill 17-1/2" hole to 3500' TVD, 4459' MD. 3. Set 13-3/8" casing and cement same. Test casing to 2500 psi for 30 minutes. NU BOPs and test. 4. Pick up 12-1/4" bit and BHA. Drill 10' of new hole and perform leakoff test. Maintain angle and direction to 8689' TVD, 12,63 I'MD (top of the Sag River Sand). 5. Set 9-5/8" casing and cement same. Test casing to 3000 psi for 30 minutes. 6. Drill 10' ofnew 8-1/2" hole and perform leakoff test to 12.5 ppgEMW. Drill 8-1/2" hole to TD at 9119' TVD, 13,309' MD (150' MD below the OWC). 7. Run wireline logs as programmed. 8. Set 7" liner and cement same. 9. Clean out liner and test casing to 3000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. 10. Release rig. Run cement evaluation logs and gyro after rig release. 11. MIRU completion rig. Run 5-1/2" tubing and packer assembly. Nipple up 5-1/2" tree and test to 3000 psi.. 12. Rig up wireline and perforate. 0il & Gas Cons. commission , gnohorage NOTE; a, PBU DS 12-32 OPERATIONS SUMMARY CONT. Excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interuption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. Well within 200' of the proposed well are: Co d, e° fo DS 12-27 54' @ 816' TVD / 818' MD DS 12-26 62' @ Surface DS 12-28 169' @ 1002' TVD / 1006' MD DS 12-02 175' @ 500' TVD / 500' MD DS 12-25 180' @ 500' TVD / 500' MD DS 12-03 193' @ Surface The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi / ft). Based upon previous logs on DS 12, no potential productive zones are anticipated above 4000' TVD. No potential hazardous levels of H2S are anticipated in this well. ~!as~ 0il & Gas Cons. ~nch0rage 1000 2000 3000 4000-- z [--, 5000-- cEE ~> 6000 7000 [ 0u00 DS 12-32 2.5 7.5 12.5 ]000 2000 ' 2'0" CA$iF,~ 300u 40[30 = 500 )C TVD = 10 TVD 2270 MD 318' 7224 MD = ~ TVD = :U/KINGAK SAG RIVE '8" C_ASIN( ~SHUBL ;ADLEROCI Ir,.) CONTA, O/W COt TD/A 50()0 ARC, $59 DEP = 600O 9000 AL/ ~CALI:: 1 IN SHL: 1030' SEC: ?7, THL: 825' RF~: 16: SKA, FSL, 125' FV~ 1ON, R15E, U NL', 9200' FI II~N: R15F; [! INC. 7000 2523 DE = 837 CASING 1'VD --- 350 ) MD -- 4, '"' ..l N 67 DEG 25 Mil ;E 89191FT(TO TARtET) "~VERAI3E ANaL, El 6O~G 34 MIN/ 10324 D,.Pe = 6863/ 1984 I'VlD I~ 11521 DEP_=j J '""x7787 I '~_.. 2332 .5 :2.5 37.5 47.5 E( · K. LC g-5 TOF~. / TVD = 8589 MD = 1 R TVD = 8689 MD = ;TVD = 8~89 MD-- ,IR 1 VD = B/lEt MI.} TM -liT TVD =18789 MD ,?,T TVD = 3804 MD GET TVD~= 8814 I~1 ITACT TVID= 9024 ~J.~.R_T~q = 9!1,9. 2474 DEP 12631 DEl 12631 DEP 12578 Ol:i = 12789 DI = 12812 DJ ~ = 12886 I ~D = 1315.., AD = !330 = 8523 ' = 8645 -- 8645 J -' UUUZ -'P = 8767 !P = 8785 )I~P = DEP --'- 9C 9 DF..P--~ 9 8000 I53 lO00O 11000 0 1000 2000 3000 ~003 500O 6000 700O 80OO 9000 t0000 (1_ w d w w -) co -1000 (_0 0 © © Z E - kl COOROINATES ,D ] 000 2000 3000 4000 SOOO 6000 7000 8000 9000 ! 0000 11000 ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' I I I I I , ~ , , , , ' ' ' ' ' ' I I I I I I , , , ~ , I I I I ~ I I I I I I I I ' ' ' ' ' ' ' ' ' ' ' ' ' ' ~ ' ' ] ' ' ' ' ' I DS 12-32 2000 3000 4000 5000 6000 7000 8000 9000 10000 1 ! 000 E - N COORDINFtlES Z o -1000 CD CD CD CD O E - N OOORBI 0 1000 2000 S000 4000 5000 6000 7000 8000 9000 10000 11000 - t 000 0 1000 2000 3000 4000 5000 6000 7000 8000 gO00 10000 11000 E - N COORDINBTES Z E - 14 COOROINPI'I'ES -300 -200 - 1 O0 0 1 O0 200 300 4O0 81~ 3906 0 0 I ~ I ' ' t , , , ! I I ' ' ' ' ' ' ~ ' I I I ' ' ' ' ' I ' ' ' ' ' ' ' ' ' ' ' I I I ' ' I , ' ' ' ' ~ I I I ,~ ' ' ' ,' ' ' ' ' ' "OS 12-28,./'3710 / OS 2-2 ! '- ,, /2875 /4027 5 3475 S 12-28 OS 2-25 . .,, . ,, ,. ,. , , ~,, -300 -200 - 100 0 100 200 300 400 E - 1,4 COOROINI=tlES ~9 DS 12-32 MUD PROGRAM DEPTH DENSITY OWD) (PPG) PV YP INT. 10 min (CP) (#/100sqft) GEL GEL FL OIL SOLIDS TYPE (cc/30min) % % Surf 8.8 Funnel 40 to to 100 to 13-3/8" 9.2 to 60 Csg Pt. 250 30+ 50+ 25 0 8 Gel - Benex Spud Mud 13-3/8" 8.8 Minimum 2 2 5 25 0 3.5 Low Solids to to Possible to to to to to Non-Dispersc(t K-10 9.6 4 4 10 10 6.5 K-10 9.6 10 6 4 8 8 2 4 Low Solids to to to to to to to to to Non-Dispersed 9-5/8" PT 10.2 20 10 8 12 6 5 8 9-5/8" 8.8 5 2 2 5 8 2 4 Low Solids to to to to to to to to to Non-IDispersed TD 9.2 10 4 4 10 6 5 8 The above properties are to act as a basic guidline, actual fluid properties are to be adjusted to the hole conditions encountered. EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaner and centrifuges MUD SYSTEM NABORS 28E MUD CLEANER MUD CLEANER SAND TRAP 4 BBLS TRIP TANK PIT I 171 BBLS 130 BBLS PIT 2 PIT 3 81 BSLS 137 BBLS PIT 5 117 BBLS PIT 4 179 BBLS PILL PIT 20 BBLS PIT 6 135 BBLS CAVIEM SB-7 MUD CLEANERS (2 @ 750 GPM EACH) DESANDER 3 X 12" DIAMETER CONES DRILCO DEGASSER BRANDT CENTRIFUGE MUD PUMPS: 2 CONTINENTAL EMSCO FB-1600 DACRO GAS BUSTER JG 8/6/87 1:5-5/8" PSI BOP STACK L-,/- RAM ACCUMULATOR CAPACITY TEST I I IpANNULARRi REVENTE I BLIND RAMS) I cDRILLINGi~ SPOOL PI PE RAMS SPOOL ~ CSG ~ 1 ~-~/8" HEAD ALL BOP EQUIPMENT 5000 PSI RATED 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS :5000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. R U N I N LOC K DOW N SC R EWS. $.CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4.FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A :::)SO PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO $000 PSI AND HOLD FOR A MINIMUM OF $ MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :5 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST $ MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST $ MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. 1Z. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST :5 MINUTES. 1:5. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. 1 4. TEST STANDPIPE YALYES TO $000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. GSW 11/07/BB NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. SCHEMATIC FILL-UP LINE I RISER I FLOWLINE ! I 2000 PSI DIVERTER I 10" BALL VALVE LL VALVE II I I I I CONDUCTOR NOTE' ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 RESERVE PIT 10" VENT LINE WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. GSW 1/13/8 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~Pd, ~ 1. (2) (2 thru 8) (8) (3) Admin ~C ~ 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) (5) BOPE ~.~.~ /-~o-gq (23 thru 28) Company '~,z-z'. c) Lease & . YES Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. ~_~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ............ ' ......................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Well No. NO 23. 24. 25. 26. 27. 28. REMARKS Is conductor string .provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. . (6) OTHER '(2~thru 31) ' (6) Add: Geology: Engineering: . ~.cs L/d;~%w ~ rev: 01/10/89 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. POOL gqo / .9o INITIAL CLASS STATUS Additional Remarks: GEO. UNIT ON/OFF 8lb . /~Z' ~ /Y--~,f~ AREA NO. SHORE ' ' oz' /z-.z7 cO_.. o ~o 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. ,o * ALASKA COMPUTING CENTER * * . ****************************** * ............................ . ....... SCHLUMBERGER ....... . ............................ . ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 12-32 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292191000 REFERENCE NO : 98556 NOV 0 6 Anchorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: **** REEL H~ER **** SERVICE NA~iE : EDIT DATE : 98/11/ 2 ORIGIN : FLIC REEL NAME : 98556 CONTINUATION # : PREVIOUS REEL : COiV~MENT : ARCO ALASKA INC., PRUDHOE BAY, DS 12-32, API# 50-029-21910-00 * * * * TAPE HEADER * * * * SERVICE NAi~iE : EDIT DATE : 98/11/ 2 ORIGIN : FLIC TAPE NAME : 98556 CONTINUATION # : 1 PREVIOUS TAPE : COMI~EN~ : ARCO ALASKA INC., PRUDHOE BAY, DS 12-32, API# 50-029-21910-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 12-32 API NUMBER: 500292191000 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 2 -NOV- 98 JOB NUMBER: 98556 LOGGING ENGINEER: BOEHME OPERATOR WITNESS: R. WHITE SURFACE LOCATION SECTION: 17 TOWNSHIP: 1 ON RANGE: 15E FNL : FSL: 1030 FEL: FWL: 125 ELEVATION (FT FROM MSL O) KELLY BUSHING: 74. O0 DERRICK FLOOR: 73. O0 GROUND LEVEL: 41. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 13499.0 2NTD STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH 88888.0 13077.5 13074.0 13073.5 13034.5 13034.0 13022.5 13022.0 12999.5 12984.0 12942.0 12920.5 12911.5 12906.0 12891.0 12873.5 12870.0 12867.5 12865 5 12853 0 12842 0 12833 0 12791 5 100 0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88889.0 13078.5 13074.5 13035.5 88888.5 13074.5 13035.5 13023.0 13023.0 13001.0 13001.0 12985.0 12985.0 12943.0 12943.0 12920.5 12920.5 12912.0 12912.0 12906.0 12906.0 12891.0 12891.0 12872.5 12872.5 12869.5 12869.5 12867.5 12867.5 12865.0 12865.0 12852.0 12852.0 12841.5 12841.5 12832.5 12832.5 12791.5 12791.5 100.0 100.0 REMARKS: CONTAINED HEREIN IS THE CNTG DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 12-32 ON 27-SEP-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTG PASS #1 GRCH TO THE BASELINE GAF~IA MY PROVIDED BY THE CLIENT (GR.BCS) ; AND CNTG PASS #1 NPHI TO GR.BCS. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SOqv~rzARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13087.0 12702.0 CNTG 13098.0 12702.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH GRCH CNTG .............. REMARKS: THIS FILE COAUfAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #i. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: TYPE REPR CODE VALUE 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 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1283895 O0 000 O0 0 1 I 1 4 68 0000000000 NRAT CNTG 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1283895 O0 000 O0 0 1 i 1 4 68 0000000000 NCNT CNTG CPS 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1283895 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13341.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 CCL.CNTG GR.BCS 23.307 DEPT. 12702.000 NPHI.CNTG 49.503 ENPH. CNTG 46.771 CPHI.CNTG NRAT. CNTG 4.405 CRAT. CNTG 4.118 ENRA.CNTG 6.192 NCNT. CNTG FCNT. CNTG 342.451 CNTC. CNTG 1414.340 CFTC. CNTG 350.962 CNEC. CNTG CFEC. CNTG 426.485 GRCH. CNTG 59.259 TENS.CNTG 4188.000 CCL.CNTG GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 47.024 1439.227 2640.921 -0.066 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .00i SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13087.0 12696.0 CNTG 13098.0 12686.0 $ 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 CNTG 88888.0 88888.0 88887.5 13087.5 13087.0 13082.0 13082.0 13075.0 13075.0 13074.5 13074.5 13071.5 13072.0 13063.0 13064.0 13043.5 13044.0 13023.5 13023.0 13012.0 13012.0 13002.0 13003.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 12988.5 12982.5 12972.0 12968.0 12966.0 12945 5 12942 0 12928 5 12923 5 12914 5 12900 5 12893 5 12891.5 12876.5 12873.5 12870.0 12866.5 12859.5 12853.5 12845.0 12842.5 12830.5 12825.0 12824.5 12807.0 12791.5 12790.0 12784.5 12783.5 12778.0 12775.5 12761.0 12756.5 12742.0 12740.0 12736.5 100.0 $ 12989.0 12972.5 12966.5 12943.0 12928.5 12914.5 12891.0 12872.5 12869.5 12852.5 12841.5 12824.5 12807.5 12791.5 12784.5 12778.5 12983.5 12968.5 12946.5 12923.5 12900.5 12893.0 12875.5 12866.0 12858.5 12844.0 12830.0 12824.0 12790.0 12783.0 12775.5 12761.0 12755.5 12742.5 12740.0 12735.5 12736.5 99.0 100.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 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 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNTG CPS 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1283895 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13097.500 NPHI. CNTG 22.761 ENPH. CNTG 30.291 CPHI.CNTG NRAT. CNTG 2.581 CRAT. CNTG 2.651 ENRA.CNTG 4.691 NCNT. CNTG FCNT. CNTG 859.250 CNTC. CNTG 2408.706 CFTC. CNTG 920.858 CNEC. CNTG CFECoCNTG 582.623 GRCH. CNTG -999.250 TENS. CNTG 4500.000 CCL.CNTG 24.508 2492.951 2733.042 -0.025 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: DEPT. 12695.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 57.944 TENS. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13087.0 12696.0 CNTG 13098.0 12696.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 88888.0 13088.0 13082.5 13075.0 13074.0 13071.5 13043.5 13035.0 13025.0 13002.0 12992.5 12988.0 12982.5 12972.0 12970.0 12968.0 12962.0 12957.5 12942.0 12928.0 12923 5 12919 0 12914 5 12914 0 12900 5 12891 5 12885 5 12881 0 12873.5 12872.0 12870.0 12866.0 12865.5 12864.0 12859.5 12857.5 12853.5 12849.0 12844.5 12842.5 12833.0 12830.0 12825.0 12824.0 12810.5 12807.5 12791.5 12790.0 12784.5 12783.5 12778.0 12772.5 12761.5 12755.0 12739.5 88887.5 13082.0 13074.0 13072.0 13044.0 13035.5 13003.0 12989.0 12972.5 12969.0 12962.5 12943.0 12928.0 12914.5 12891.0 12885.0 12872.5 12869.5 12865.0 12863.0 12857.0 12852.5 12841.5 12833.0 12824.5 12807.5 12791.5 12784.5 12778.5 12772.0 12739.5 88887.0 13087.0 13075.0 13044.0 13025.0 12993.5 12984.0 12970.5 12958.5 12923.5 12919. 0 12915.0 12900.0 12891.5 12880.5 12871.0 12866.0 12858.5 12848.0 12844.0 12829.5 12824.0 12810.5 12790.0 12783.5 12772.0 12761.0 12754.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 10 100.0 $ 100.0 99.0 REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORM_AT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 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 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 11 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) CNEC CNTG CPS 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1283895 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13097.000 NPHI.CA~fG 22.155 ENPH. CNTG 28.259 CPHI.CNTG NRAT. CNTG 2.609 CRAT. CNTG 2.618 ENRA.CNTG 4.479 NCNT. CNTG FCNT. CNTG 778.866 ClFTC. CNTG 2148.200 CFTC. CNTG 827.352 CNEC. CNTG CFEC. CNTG 591.459 GRCH. CNTG -999.250 TENS. CNTG 4036.000 CCL.CNTG 24.225 2173. 125 2649.250 - O. 025 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 12 CNTG 1, 2, 3, $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH 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 56 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 18 65 68 65 66 68 66 0 65 FT 66 68 66 1 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 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1283895 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 13 ** DATA ** DEPT. 13097.500 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV -999.250 NCNT. CNAV FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV CFEC. CNAV -999.250 GRCH. CNTG -999.250 DEPT. 12702.000 NPHI. CNAV 50.284 NRAT. CNAV 4.343 CPHI.CNAV CRAT. CNAV 4.161 ENPH. CNAV 47.330 ENRA.CNAV 6.237 NCNT. CNAV FCNT. CNAV 340.999 CNTC. CNAV 1431.251 CFTC. CNAV 357.120 CNEC. CNAV CFEC. CNAV 423.125 GRCH. CNTG 59.259 -999.250 -999.250 -999.250 46.668 1423.863 2639.206 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 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 SUFmLARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 13119.5 12701.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 14 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): 27-SEP-98 8Cl -205 2140 27-SEP-98 13110.0 13104.0 12750.0 13098.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMP. NEUTRON $ TOOL NUMBER SGT-L CN T- G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 13499.0 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) : PUMPED CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS BHC 3/12/98. PI 400 BBL CRUDE AT 5.3 BPM PRIOR TO LOGGING. LOGGED 3 PASSES FROM TD - 12750' AT 30 FPM. LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 15 PUMPED CRUDE AT 1.5 BPMWHILE LOGGING. FIELD PICK GOC 12980' TOLTAL FLUIDS PUMPED: 480 BBL CRUDE; 5 BBL DIESEL. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 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 76 66 1 0.5 FT 13 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 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PSI CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 RCENPS1 CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 16 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) NPOR PS1 PU 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1283895 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13119.500 NPHI.PS1 11.126 ENPH. PS1 41.585 TNPH. PS1 TNRA.PS1 1.845 RTNR.PS1 1.889 ENRA.PS1 5.758 CFEC. PS1 CNEC. PS1 2651.992 RCEF. PS1 466.538 RCEN. PS1 2506.804 RCNT. PS1 RCFT. PS1 1057.604 CNTC. PS1 1976.475 CFTC. PSI 1099.417 NPOR.PS1 GR.PS1 455.619 TENS. PSI 2100.000 CCL.PS1 -0.058 DEPT. 12700.500 NPHI.PS1 50.742 ENPH. PS1 48.302 TNPH. PS1 TNRA.PS1 4.186 RTNR.PS1 4.514 ENRA.PS1 6.315 CFEC. PS1 CNEC. PS1 2627.760 RCEF. PS1 436.665 RCEN. PS1 2415.974 RCNT. PS1 RCFT. PS1 309.555 CNTC. PS1 1425.662 CFTC. PSi 333.317 NPOR.PS1 GR.PS1 54.949 TENS.PSI 4184.000 CCL.PS1 -999.250 13. 017 460. 608 2017. 948 13. 017 51.856 416.128 1519.476 49.504 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 17 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 SUMFLARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13123.0 12691.5 CNTG LOG HEADER DATA DATE LOGGED: 27-SEP-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 2140 27-SEP-98 TD DRILLER (FT) : 13110.0 TD LOGGER (FT) : 13104.0 TOP LOG INTERVAL (FT) : 12750.0 BOTTOM LOG INTERVAL (FT) : 13098.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~MA RAY CNTG COMP. NEUTRON $ 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) : 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): TOOL NUMBER SGT-L 8.500 13499.0 PUMPED CRUDE EPITHERMAL 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 2-NOV-1998 11:23 PAGE: 18 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS BHC 3/12/98. PI 400 BBL CRUDE AT 5.3 BPM PRIOR TO LOGGING. LOGGED 3 PASSES FROM TD - 12750' AT 30 FPM. PUMPED CRUDE AT 1.5 BPM WHILE LOGGING. FIELD PICK GOC 12980' TOLTAL FLUIDS PUMPED: 480 BBL CRUDE; 5 BBL DIESEL. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 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 76 66 1 0.5 FT 13 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 C~SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1283895 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1283895 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1283895 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1283895 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1283895 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 19 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RTNR PS2 1283895 O0 ENRA PS2 1283895 O0 CFEC PS2 CPS 1283895 O0 CNEC PS2 CPS 1283895 O0 RCEF PS2 CPS 1283895 O0 RCEN PS2 CPS 1283895 O0 RCNTPS2 CPS 1283895 O0 RCFT PS2 CPS 1283895 O0 CNTC PS2 CPS 1283895 O0 CFTC PS2 CPS 1283895 O0 NPOR PS2 PU 1283895 O0 GR PS2 GAPI 1283895 O0 TENS PS2 LB 1283895 O0 CCL PS2 V 1283895 O0 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 13123.000 NPHI.PS2 20.444 ENPH. PS2 22.375 TNPH. PS2 TNRA.PS2 2.512 RTNR.PS2 2.571 ENRA.PS2 3.828 CFEC. PS2 CNEC. PS2 2692.163 RCEF. PS2 712.318 RCEN. PS2 2544.776 RCNT. PS2 RCFT. PS2 832.303 CNTC. PS2 2127.282 CFTC. PS2 865.208 NPOR.PS2 GR.PS2 271.015 TENS.PS2 1718.000 CCL.PS2 -0.024 DEPT. 12691.000 NPHI.PS2 58.874 ENPH. PS2 44.952 TNPH. PS2 TNRA.PS2 4.632 RTNR.PS2 5.147 ENRA.PS2 6.043 CFEC. PS2 CNEC. PS2 2738.827 RCEF. PS2 427.773 RCEN. PS2 2524.935 RCNT. PS2 RCFT. PS2 . 336.728 CNTC. PS2 1438.479 CFTC. PS2 319.996 NPOR.PS2 GR.PS2 50.363 TENS.PS2 3980.000 CCL.PS2 -999.250 22.216 703.264 2171.919 22.216 58.458 453.196 1469.731 58.413 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PA GE: 2O **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 7 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 SOPmL~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 13112.0 12694.5 CNTG $ 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 GR GAMMA RAY CNTG COMP. NEUTRON $ 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) : 27-SEP-98 8Cl -205 2140 27-SEP-98 13110.0 13104.0 12750.0 13098.0 1800.0 NO TOOL NUMBER SGT-L CNT-G 8.500 13499.0 PUMPED CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 21 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): EPITHERMAL 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS BHC 3/12/98. PI 400 BBL CRUDE AT 5.3 BPM PRIOR TO LOGGING. LOGGED 3 PASSES FROM TD - 12750' AT 30 FPM. PUMPED CRUDE AT 1.5 BPM WHILE LOGGING. FIELD PICK GOC 12980' TOLTAL FLUIDS PUMPED: 480 BBL CRUDE; 5 BBL DIESEL. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 22 TYPE REPR CODE VALUE 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 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1283895 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 13112.000 NPHI.PS3 16.300 ENPH. PS3 22.375 TNPH. PS3 TNRA.PS3 2.233 RTNR.PS3 2.286 ENRA.PS3 3.828 CFEC. PS3 CNEC. PS3 2692.163 RCEF. PS3 712.318 RCEN. PS3 2544.776 RCNT. PS3 RCFT. PS3 832.303 CNTC. PS3 1885.548 CFTC. PS3 865.208 NPOR.PS3 GR.PS3 345.411 TENS.PS3 2420.000 CCL.PS3 -0.024 DEPT. 12694.000 NPHI.PS3 56.821 ENPH. PS3 44.784 TNPH. PS3 TNRA.PS3 4.520 RTNR.PS3 4.372 ENRA. PS3 6.029 CFEC. PS3 CNEC. PS3 2656.992 RCEF. PS3 451.661 RCEN. PS3 2626.530 RCNT. PS3 RCFT. PS3 359.233 CNTC. PS3 1497.237 CFTC. PS3 359.264 NPOR.PS3 GR.PS3 53.438 TENS.PS3 3798.000 CCL.PS3 -999.250 18.240 703.264 1925.113 18.240 49.442 440.676 1606.590 46.824 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 11:23 PAGE: 23 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 2 ORIGIN : FLIC TAPE NAME : 98556 CONTINUATION # : 1 PREVIOUS TAPE : COIqMENT : ARCO ALASKA INC., PRUDHOE BAY, DS 12-32, API# 50-029-21910-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 2 ORIGIN : FLIC REEL NAME : 98556 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., PRUDHOE BAY, DS 12-32, API# 50-029-21910-00 WWHO id~ ' liNn g9 N]±£ Z ads 9 30~ 99 aql~ 89 ~qi~ ~O ~03 ~N 91, 1~ : .LIN~ H£d]O 3d~l ~N~d ~]d Nid]O flNO '3NI 3d09S NI~ON : NflO3 AV~ BONOQ~d : N~ AV~ ~ONOA~d : NM BglH ,~90H NfldO ,/ '~Jg'ININ'qOZ'q~ia'DN~'9~IO, ~0 6~Z£ dL~:~L 69 WVN 92 L"G :NOISiA~ · ~ enI - 2L/£/69 LO :UOT%nDe,xe to %Je%S 06 1, 1,c599'0 696~/' ~Z 1, £9699'Z~ F..£ 00') ~ 9 "0 L~9~' ~/_ I, 00Zg6"9£ £ O"Tg ~99 "0 Z 1,6£"£Zi, 6~££Z"9~/ 1,~ ~/1,g 6 ~ '0 g6~ 1," ~7Z 1, ~Z06£'01, ~1,g~Z6~"O c~ZO9'Z 6~0~91,9'0 669 1,'9Z1, Z'7 I,~ 1,0' ~ Z991,699"0 6c~ I,~'9Z 1, 09~ I,C~99"0 09~99'0 dW~£ 60692'~k O000g~£'O ~;~'~g' 0 I, ~ 1,0~'6~ 000~62 "0 ~ £~ F_.6 '61, gZ606'01, 666~'6~ 0000962'0 000~60£'0 91,9Z09'6 ££960'9~ O00ggO£'O 6gO~£'Z~ 000~g62'0 1,6g9g~ '6 1,09 · 2~ 000000£'0 61,0g0 1,'g ~6Z£'g~ O00gZ62'O O00SZ6~"O 6Z6£6~"2 qd2£ N~ 06'Lf29 ~8~0 'Z~ 0~26g1,'0 1,6'00~9 £1,"79'0£ 000Z61,'0 ~'0629 ~6£2'96 ~g'~9 ~9'0£ £0 'Z~29 ~LL'6~2 ZgZ"6Lk 60'~Z29 ~9£~'02 ~62'£9~ ~ZgZ6k'O 1,6'2029 ~009'22 Z06'02~ SZgZ6L'O ~009'22 0~I3 ~ $31A~ ~66 9£699"L~ 09866'£L £09£L'gL OZD66"~L O~9"LO£L Z266~'6L £Zg'ZO£L 6~6~'gD 0Zg66'2~ ~9L"L9£L 99~2Z'~6 LO2'Z~ZL ~06£Z'~2 6Z6'~g2L ~02~9'66 2ZgLO'L~ £60£'~Z6 L£~66'9L 3~ OdS (0 #2dXJ.) ~£~09'9£ Z0260'2~ 000'£~0£k F...99 I,~ ' 0 1, 9LS969'6- 9£609' I,~ 000'££ I,£ !, 6~Z1,9Z'6 1,99~79' g !, 000' £~ i,£ !, OZg6L£'g £g~6~'~- Z~6£'6 1,£966Z 'Z Z2~O6'9g- 9£Z~O'k~ 000'££E£1, O~OOZ9'g O00"£g££L O~OOZ9'g 0£6~6'9~- 000'££~£L dS 30~ HZd2a "Id 2.L gl, g9 GqI3 '1S 2~J 91, 89 .L~2~ g9 SH~c~ D~O NDNI £IN~ ~ 89 N~±£ 0 ~ B9 0a$ 6 [ ~9 ~ODZ ~ ~9 ~ 9 ~ ~9 aSS L ~9 DN3 L 99 ND 2 L g9 q~3 dN~S ~aog ~N~N (~9 02 gNaSH W~d HidBO DNO #~dAi) OWOD~W i~W~04 00'ZI, Z21, 6'"/~ g I, 6 I,, "0 c~£g9'~91, Z i,Z !,062"0 "TZ6g ' ~9 I, 6Zg2"Z9L 000~689"0 ~S66'g9~ S06S"0~ £~ff£'OZL ~0££~99'0 ~£959"82 O000'ZgL"O O0"O000L 6~9~'~0L OSZ£OY2'O ggLgOZ'S OZZB6'LL 62~ZZ'S9 0000~0£'0 ££Y££"SL 9Z,~ I, ' I, I, S L~O~' L9 00092~£'0 O2YSL'BY LgLYZ'L9 0~29g02"0 96g£~L'~ Z/.~O I, · ~ ~ 2£~£6'09 ONION3 60LZ'9~L LO-B66~Zg~£'O Z02'~96~ Og96L'69 1,0- :J 1,00~;Z69 "0 2c~£ '986~ !,~0£' L~7 !, 656ZS'Z~ OGZ£L9L'O g99'6~09 gOO~"£g L$~9SL'$ OgZ£SL2'O 02g'6229 Z2~62'Z9 6$Z~'ZO£ S~BOS~'O 926'B029 2Z6Z9'g~ Z'~ i.£' Z !. 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NI SO~OD]~ 9~101 ~0 2~/£/6~ = H~dBO 9NION~ O0 '£ L~£ ~ e~e~ WB9I~I gqlB = Nid~O Bd~£ ONII~IS : SO~OD~W ~1~0 9~£01 £0--qSS~£~92 '0- 09B66£~'0 0S~66'~ ~O-B£+/B ~90~'0 0S866'+/B 0~6Z~9'~ OOE~6Z~'O 0~66'~ ~££~06£'0 ~96~'~9~ L696~Z~'O 0~66'~L 896~£'98 gY9ggZ'9 0£~62£9'0 OgB66'~ gY6S90'~ 0~9+/£ L9'O 0~g66'¥~ §0Z6££,8 B6B6'LOL 608gg£'2 9£9g 1,~ 'E 96c~66'~Z 9~0992'8 ZZ6~'~66 $0982£'2 g6SOZ'g~ 6Z969S'g 9E~29~'2 gZ99L'gE ZOZ~OO'g ~£66~'~ 9Z0£~'82 0Z~£90 'g £996'g££ Z2gE99Z'O- 9~269/_'0- 96 c~66 ' i,Z £Z6L~£'6 ~LBZO0'6 gg6'ZLOL LO-~g~Z969~'O- 696Z99'g £Zg2'~96 LO-D6~L~Z~L'O gZ99L"~Z LO-~SZ~6EOL'O- 6£L'B9ZL 20-26E6£gE+/'O- EO-~6~E$6E 'O- Z6L6'LO£ ooo' gz 6~ZZ6'ZL 9£ZgOL'~7 0 L~7'602 I, 90gO' Z~Z 0 i, 6 ' 02~9 Z££g'"ZO~ 99Z'9~6Z 661, LZ6' gJ 000' £9~ I,. G?£69g 'Z 9ZO' i, OZ~ 2ZL' 02 ~79 01.~7~'~0£ £~O'~Lg6 L90£22 '~ 000'£96EL gOZ'~2~L LL£L'~O£ , ~O~'C~'~ +~2Z£~9'9 g £.6'62£ L ~'~!, "60G9 06~'926g nnn - C li'n c L TOTAL RECORDS IN THIS LOGICAL REEL : 565 TOTAL RECORDS IN THIS PHYSICAL REEL: 555 End of execut±on: Tue 28 MAR 89 12:54D Elapsed execution time = 2 minutes, 40.0 seconds. SYSTEM RETURN CODE = 0