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100-238
1a. Well Status: GINJ Oil 1b. Well Class: Exploratory Service 5 Hilcorp North Slope, LLC 14. Permit to Drill Number/Sundry 100-238 6/24/1973 6/26/1973 GL 4a. Surface: Top of Productive Interval: 4511' FSL, 1063' FEL, Sec. 11, T10N, R14E, UM Total Depth: 4511' FSL, 1063' FEL, Sec. 11, T10N, R14E, UM 4511' FSL, 1063' FEL, Sec. 11, T10N, R14E, UM Surface: x- y- Zone -685953 5939829 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 6/16/2020 15. 50-029-21817-00-00 16. PBU OWDW-SW Well Name and Number: Surface / Surface 42.00 17. TPI:y- Zone -685953 ASP 4x-5939829 Total Depth: x-y-Zone -685953 ASP 45939829 2250' / 2250' None DNR Approval Number:19. 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: SP / DIL, 4-Arm Caliper CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 72# 17#L-80 Surface Surface 120 sx Arctic Set 25. GRADE PACKER SET (MD/TVD) 26. 2-7/8" 6.5# L-80 1941' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Injection N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: Surface Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): N-80 100'13-3/8" 5-1/2"Surface 2215'12-1/4"3760 sx Arctic SetSurface2215' 1 cup AS I Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 100' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028311 320-218 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF Surface (attached)5 KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 56.50 Water Depth, if Offshore:13. N/A Zero API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: N/A 1850' (Approx.) Submit within 30 days of Completion, Suspension, or Abandonment PRUDHOE BAY, PRUDHOE UNDEFINED WDSP By Jody Colombie at 3:41 pm, Jul 15, 2020 Abandonment Date 6/16/2020 HEW RBDMS HEW 7/17/2020 xGDSR-7/20/2020SFD 7/17/2020MGR21JUL2020 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Authorized Name: Authorized Title: Authorized Signature with Date:Contact Phone: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes Top of Productive Interval Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Daily Work, Photo Documentation, Wellbore Schematic DiagramList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 564-4763 Carrie Janowski Sr Regulatory Technician Digitally signed by Carrie Janowski (4185) DN: cn=Carrie Janowski (4185), c=US, o=Hilcorp North Slope, LLC, ou=Prudhoe Bay East, email=Carrie.Janowski@hilcorp.com Date: 2020.07.15 13:45:51 -08'00' Carrie Janowski (4185) ACTIVITYDATE SUMMARY 6/16/2020 OWDW-SW P&A: (Group Excavation) Pad elevation at 41.9' and Tundra elevation 37.4'. Cut previously suspended wellbore at 9.7' below pad grade. Leaving well 5.2' below Tundra level. AOGCC Adam Earl witnessed cut. Tubing had a 0.3' void. Filled with 1 cup of AS1 cement. Cement tops and Marker plate installation witnessed by AOGCC Guy Cook ***Back fill excavation*** Daily Report of Well Operations PBU OWDW-SW MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission a TO: Jim Regg �ZS DATE: 6/16/2020 P. I. Supervisor ��i FROM: Guy Cook SUBJECT: Surface Abandon Revisited Petroleum Inspector PBU OWDW-SW - BPXA PTD 1002380; Sundry 320-218 6/16/2020: 1 arrived on site and met John Perl with BPXA. We discussed the job and then headed to the well to confirm the cut-off depth and that there was good cured cement to surface before the installation of the identification plate. I also confirmed the proper information was on the identification plate as well. This well was abandoned in 2012 and the surface abandonment report dated 4/9/2012 (AOGCC witnessed) indicated the well was cut at a depth 3 feet below the pad level instead of at least 3 feet below original tundra level. The well status per AOGCC was left as Suspended, not P&A. Today's inspection followed BPXA's work to cut the well at the proper depth for P&A approval. The casing was confirmed to be cut off at 5.2 feet below tundra level. I then inspected the identification plate once it was installed. -The appeared to be solid with good penetration and to have sealed off the casing bore from the environment. After the inspection was complete, I gave Mr. Perl the go-ahead to bury the well. Attachments: Photos (3) 2020-0616_Surface_Abandon_PBU_O WD W -S W_revisited_gc. docx Page 1 of 3 0 00 M r 0 CN N r� cU 0U U m0 Q TO y � N V N O N_ O O 3 - U) d O I Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:100-238 6.API Number:50-029-21817-00-00 BP Exploration (Alaska), Inc 5. Field/Pools: PRUDHOE BAY, PRUD+2( UNDEFIN(' WDSP 9. Well Name and Number: ADL 028311 Property Designation (Lease Number):10. 8. PBU OWDW-SW 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 5 Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG 5 Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 2250 Effective Depth MD: L-80 11. June 10, 2020 Commission Representative: 15. Suspended Contact Name: Worthington, Aras J Contact Email:Aras.Worthington@bp.com Authorized Name: Worthington, Aras J Authorized Title:Interventions & Integrity Engineer 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: OtherAlter 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): 2250 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 1902 / 1902 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 27 - 2215 27 - 2215 14. Estimated Date for Commencing Operations: BOP Sketch 28 - 100 Structural Proposal Summary 13. Well Class after proposed work: 2-7/8" Baker F-1 Packer None 2-7/8" 6.5#24 - 1941 Production Surface Surface Surface None 29 - 101 2670 5-1/2" 17# L-80 Contact Phone:+1 907 564 4102 Date: 72 493013-3/8" 72# N-80Conductor 6280 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 2188 7740 Intermediate Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:20 pm, May 28, 2020 320-218 Aras Worthington Digitally signed by Aras Worthington Date: 2020.05.28 14:44:01 -08'00' DSR-5/28/2020 X MGR29MAY20 10-407 DLB 05/29/2020 Yes equired? Comm 6/1/2020 dts 6/1/2020 JLC 6/1/2020 RBDMS HEW 6/4/2020 OWDW-SW Plug and Abandon Intervention Engineer Aras Worthington (907) 564-4102/(907) 440-7692 Expected start date: June 10th 2020 History Prudhoe Bay Unit Oily Waste Disposal Well Southwest (OWDW-SW) was one of the EPA permitted Class I disposal wells located at Pad 3 near DS 6. The wells were originally drilled for a permafrost test in the mid 1970’s and disposal began in 1976. The wells are perforated just below the permafrost at about 1980 feet. In 2012 the well was P&A’d with cement to surface in all tubing, Control line, and annuli. The well was cut off ~3’ below pad level and the annuli were topped off with cement. The name cap was installed via tack-weld. The well has since remained in suspended status. Objective Excavate and cut off all casings 3’ below original tundra, permanently install well name cap, and backfill excavation. Procedural steps Special Projects 1. Excavate and Cut off all casings 3’ below original tundra level. 2. AOGCC witness of cut-off casings before any top job commences. 3. AOGCC witness cement tops in all annuli. 4. Bead weld marker cap on outermost casing string (13-3/8” Conductor). Photodocument all steps and AOGCC witness of installed cap. Marker cap to read as follows: BP Exploration Alaska, Inc OWDW-SW API No. 50-029-21817-00 PTD No. 100-238 24 Hour notice to AOGCC to witness. BP EXPLORATION ALASKA INC. Obp 900 E BENSON BLVD ANCHORAGE ALASKA, 99508 I(yj.NJ QQ Correction to OWDW Well Coordinates AOGCC What happened: We discovered that the reported coordinates for the following oily waste disposal wells (OWDW) were approximately 100 feet off from their actual locations: OWDW-C, OWDW-NE, OWDW-NW, OWDW-SE, and OWDW-SW. What went wrong: 1) We found no evidence that an as -built survey was performed for the original (1973) observation well completions. 2) These observation wells were converted to disposal wells circa 1976-78, again with no record of as -built survey. 3) When these wells were worked -over in 1985, the rig completion forms used location references that were incorrect and in a non-standard format. 4) The locations were revised c. 1988 and recorded in the standard location format (offset distances from section lines). No evidence was found to indicate that these revised locations were verified by field survey. 5) The revised locations all had 'from north line' (FNL) measurements that fell approximately 100 feet short of their actual locations. 6) The erroneous FNL measurements were used to compute the coordinates of these wells. The resulting coordinates were all approximately 100 feet northerly of the actual well locations. What has been done in response: 1) As -built surveys were performed on 4 of the 5 OWDW wells • These surveys were certified by a registered Professional Land Surveyor (PLS) • The new coordinates were verified by a BP surveyor before and after being input into our system of record. 2) The 5th well (OWDW-SW) was suspended in 2012. The wellhead was cutoff below pad -level. • A BP surveyor has computed 'best -estimate' coordinates, based on historical records. These coordinates are estimated to be within +/- 4 feet of the actual location. • The best -estimate coordinates and the associated uncertainty were input into our system of record. 3) A BP Surveyor performed a fieldwide audit on all existing wells in the Prudhoe Bay Unit. No errors of similar magnitude were detected. Barriers in place to prevent this from happening again: 1) The fieldwide well audit verified that coordinates for the other existing wells do not suffer from the same problem. 2) All new 'grassroots' wells require an as -built survey, certified by a registered PLS. i�i7t1 n• `��%l — Karl H. Kyzer, PLS Lead Surveyor, BP Exploration Alaska Inc. May 7, 2019 North America - ALASKA - BP PBUSAT OWDW OWDW-SW - Slot SW OWDW-SW 500292181700 Design: OWDW-SW Final Survey Report 10 January, 2019 n n J� Company: North America - ALASKA - BP Protect: PBUSAT Site: OWDW Well: OWDW-SW Wellbore: OWDW-SW Design: OWDW-SW BP Final Survey Report Local Coordinate Reference: Well OWDW-SW-Slot SW TVD Reference: KB @ 56.50usft (5: SW 6/24/1973 00:00) MD Reference: KB @ 56.50usft (5: SW 6/24/1973 00:00) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Protect PBUSAT, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean San Level Geo Datum: NAD27' OGP-Use AK [4267'15864] - Using Well Reference Point Map Zone: NAD27' OGP-Use AK / Alaska zone 4 [26734.1586, Using geodetic scale factor Site OWDW, TR -10-14 Site Position: Northing: 5,937,242.500 usft Latitude: 70' 14' 1.231 N From: Map Easting: 683,394.810 usft Longitude: 148° 31'9.716 W Position Uncertainty: 0.00 usft Slat Radius: 0.000 in Grid Convenience: 1.39 ' Well OWDW-SW - Slot SW, OWDW-SW Well Position +N/S 0.00 usft Northing: 5,939,829.000 usft Latitude: 70' 14'26.047 N +E/ -W 0.00 usft Easting: 685,953.000 usft Longitude: 148'29'53.541 W Position Uncertainty 4.00 usft Wellhead Elevation: usft Ground Level: 42.00 usft Wellbore OWDW-SW Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°) (nT) bggm2007 4/17/2000 27.15 80.79 57,474 Design OWDW-SW Audit Notes: Version: 2 Phase: ACTUAL Tie On Depth: 56.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 56.50 0.00 0.00 0.00 Survey Proaram Date 1/10/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 2,200.00 Survey $1 (OWDW-SW) BLIND Blind drilling 1/10/20198.56:22PM _ Pace COMPASS 5000.1 Build BID .; Company: North America - ALASKA - BP Protect: PBUSAT Site: OWDW Well: OWDW-SW Wellbore: OWDW-SW Design: OWDW-SW Survey BP Final Survey Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well OWDW-SW - Slot SW KB (off 56.50usft (5 : SW 6/24/1973 00:00) KB @ 56.50usft (5 : SW 6/24/1973 00:00) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 MD Inc Azi (azimuth) TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (usft) 56.50 0.00 0.00 56.50 0.00 0.00 0.00 5,939,829.000 685,953.000 0.00 0.00 100.00 0.00 0.00 100.00 43.50 0.00 0.00 5,939,829.000 685,953.000 0.00 0.00 2,200.00 0.00 0.00 2,200.00 2,143.50 0.00 0.00 5,939,829.000 685,953.000 0.00 0.00 2,250.00 0.00 0.00 2,250.00 2,193.50 0.00 0.00 5,939,829.000 685,953.000 0.00 0.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,215.00 2,215.00 51/2' 5.500 8.500 100.00 100.00 13 3/8" 13.375 17.500 Checked By: Approved By: Date: 1/10/2019 8.56r22PM Pape 3 COMPASS 5000.1 Build 81D STATE OF ALASKA *ALASKA OIL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Well Inspection IZI 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 100-238 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 6. API Number: 50-029-21817-00-00 7. Property Designation (Lease Number): ADL 0028311 8. Weil Name and Number: PBU OWDW-SW 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUD UNDEFIN WDSP,---., 11. Present Well Condition Summary: Total Depth: measured 2250 feet Plugs measured 24/1928 feet true vertical 2250 feet Junk measured feet " J, ) Effective Depth: measured 24 feet Packer measured 1902 feet Packer true vertical 24 feete true vertical 1902 feet t �'<3r1�::� �,,,. Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 72 13-3/8" 72# N-80 28-100 28-100 4930 2670 Surface 2188 5-1/2" 17# L-80 27-2215 27-2215 7740 6280 Intermediate Production y�°° ®� (figg Liner b RED INO�� Perforation Depth: Measured depth: 1980-1989 feet 1989-1992 feet 1992-1996 feet 1996-2005 feet True vertical depth: 1980-1989 feet 1989-1992 feet 1992-1996 feet 1996-2005 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 24-1941 24-1941 Packers and SSSV (type, measured and 2-7/8" Baker F-1 Packer 1902 1902 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: (required Per 20 AAC 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development ❑ Service m Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Catron, Garry R (Wipro) Email Garry.Catron@bp.com Printed Name Catron, Garry R (Wipro) Title PDC Principal Engineer Signature 61 Phone +1 907 564 4424 Date 8/6/15 Form 10-404 Revised 5/2015 V TL Ej / Z /J.5 Origin@I;vi ly 1 4 2015 Fluids Summary Bbls T e No Fluids Pumped. • • Suspended Well Site Inspection Form s year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT OWDW-SW Field/Pool: PRUDHOE BAY/ PRUDHOE UNDEFINED WDSP Permit # (PTD) 100-238 API Number: 50029218170000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 4/9/2012 Surface Location: Section: 11 Twsp: 10N Range: 14E Nearest active pad or road Drill Site 06 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean, active injection pad (Pad 3) Pad or location surface: clean Location cleanup needed: none Pits condition: N/A Surrounding area condition: clean Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: Samples taken: none none Access road condition: good Photographs taken (# and description): general area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition N/A - wellhead cut-off below pad level, marker plate welded and back filled Cellar description, condition, fluids: N/A Rat Hole: N/A Wellhouse or protective barriers: N/A Well identification sign NIA Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (# and description) general area Work Required: none Operator Rep (name and signature): Whitney Pettus G ' = AOGCC Inspector Matt Herrera Other Ob, rs: Inspection Date: 7/12/2015 AOGCC Notice Date Time of arrival: 8:20 AM Time of Departure: Site access method' truck 8:25 15 -EOWDW-NW +OWDW-NE OWDW-NW OWDW-NE 1.OWDW-C OWD W -C +OWDW-SW t}+OWDW-SE OWDW-SW OWDW-SE 0.003 0.0015 0 0.003 Miles Legend Pipelines (General) ---Abo\c timund I3uricd Pipelines (Detailed) Oii (iF.. -- \\ \6 —Rcliel' —Utility tlnkno\� n Selected Pipelines 6 August, 2015 BP1\catrgl ® BP Exploration (Alaska) Inc. All rights reserved. This map is informational in nature and is presented without representations or Product of BPXA Atlas Enterprise GIS. alaska-gis.bpweb.bp.com warranties as to accuracy, completeness, or use for any purpose E 05"; m TREE = WELLHEAD = ACTUATOR = A.REV= 56.5 BF REV= 3z' KOP= Max Angle = Datum MD Datum TVD 0 SAFETY NOTE: CUT WELLHEAD/ INSTALL 0 W D w -SW MARKER PLATE (419112) 13-318" CSG 72#, N-80, ID = 12.347" 100' Minimum I©= 2.205" @ 1928' 2-7/8" HES XN NIPPLE 12-7/8'° TBG, 6.5#, L-80, EUE, .0058 bpf, ID=2.441" }—j 1941' PERFORATION REF LOG: ON +, ANGLE AT a • • + r, 19W . D8 for historicaldati ZMER 5-1/2" CSG, 17#, L-80, ID = 4.892" 1 1 2215' F -TD 2250' 560' �3/8" CONTROL LINES OPEN ENDED w /CHECK V LV S 1846' - 1856' 1–• TBG PUNCH (03/13112) 1875' - 1880'1—j TBG 1. (03/13/12) 1879 2-718 HES X NIP, 10 = 2 313" 1900 -SEAL LOC SUB, td = 2410" 1 1901 BKR GBH 22 LOC SEAL ASSY, ID = 2.370" 1902 2-7/8" BKR F1 PROD PKR 03114/12 JCWJMD SET WFD & TBG PUNCH (03/13/12 w 1 SEALBORE EXT, ID = 3 00 1992 -42-7/8--HES XN NIP. ID = 2.205' 1941 H2 -7r8 WLEG,ID=2.441' 1 1908 ELMD LOGGED (11!07106 RST/ CDL) 2070' —{TOP OF FILL (11107/0 BAY UNIT WELL OWDW-SW PERMT No 00-238 API No 50-029-21817-00 SEC 11, T10N, R14E, 1064 FEL, 668 FNL DATE REV BY CONWEWS DATE REV BY COMMENTS IPRUDHOE 06/23173 ORIGINAL COMPLETION 03114/12 JCWJMD SET WFD & TBG PUNCH (03/13/12 01101185 RWO 03/24112 TTW/ PJC CEMENT (03120 1 /1 2) 11112/06 D16 RWO 04/18112 ACB/ PJC PULL PLUG (03112/12) 10/22/07 JD/PJC NOTE TREE CAP CONNECTION 04/22112 KSB/ PJC CUT WW INSTALL MKR PLATE (4/9/12) 10/03110 WEGSV 1 SET TTP (09/28/10) BP Exploration (Alaska) 07129/11 1 TAR/ PJC I RESET XXN (7/20111) 11 1 Date Inspected: 07/12/15 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Inspector: Matt Herrera Well Name: PBU OWDW-SW PTD No.: 100238 Location Verified? Yes If Verified, How? LAT / LONG Onshore / Offshore: Onshore Operator: BP EXPLORATION AK Oper. Rep: Ryan Hayes Oper. Phone: 907-659-5766 Oper. Email: rvan.haves(ftp.com Suspension Date: 04/09/12 Date AOGCC Notified: 07/08/15 Sundry No.: 312-051 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing N/A Photos Taken? Yes IA 0 OA 0 ICondition of Wellhead: P&A cover plate under grade Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around area Follow Up Actions NONE Photo Operations aware of P&A marker below grade A,t11; 1 9 LUIS EWED BY: Supry �f PLB 12/2014 2015-0712_Suspend_PBU_OWDW-SW_mh.xlsx Suspended Well Inspection — PBU OWDW-SW PTD 1002380 Photo by AOGCC Inspector M. Herrera 7/12/2015 2015-0712_Suspend_PBU_OWDW-S W_photo_mh.docx Page 1 of 1 • SEAN PARNELL, GOVERNOR �T ALASKA OIL A" GAS 333W. 7th AVENUE, SUITE 100 CONSERYATIO COPOUS''SIO ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 8, 2012 Mr. Michael Bill Well Integrity Group BP Exploration (Alaska), Inc. �"*WED JUL 2 8 2012 P.O. Box 196612 Anchorage, AK 99501 Subject: OWDW-SW Site Inspection Waiver Request Dear Mr. Bill: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed the well file and operational summary for the plug and abandon (P&A) work that was completed on OWDW-SW (PTD 100-238) this spring and agrees with your assessment. A follow up site inspection is not necessary since the well has been capped with a steel plate and buried with fill to the exiting pad level. The procedure to abandon the well met all AOGCC requirements except the final casing cutoff was done below pad grade and not below original tundra grade. The AOGCC will keep the well status as "suspended" until the final pad abandonment has commenced at the end of the field life and the well casing is excavated and re -cut below tundra level. At that time the well will have met all AOGCC requirements to be classified as properly . WI we OWDW-SW Site Inspection Waiver Request • Page 1 of 1 Schwartz, Guy L (DOA) From: Bill, Michael L (ASRC) [Michael. Bill@bp.com] Sent: Tuesday, June 05, 2012 5:12 PM To: Schwartz, Guy L (DOA) Cc: Daniel, Ryan; Yeager, Kevin E; AK, D&C Well Integrity Coordinator Subject: OWDW-SW Site Inspection Waiver Request Guy, As we discussed, OWDW-SW was plugged with cement to surface and the casing strings were cut off below pad level, but not 3 feet below original ground level as required in 20 AAC 25.170(a)(1). A marker plate was welded to the casing strings. The plan is to remove the casing strings in compliance with the regulation at some point in the future. The 10-407 completion report filed to document the work to date showed the well status as "Suspended" as of 41109112. This note is to request a waiver under 20 AAC 25.110(n) to the requirement to inspect the OWDW SW well site within 12 months after the date of suspension (reference 25.110(e)). There is no surface well equipment to inspect as the tree and wellhead have been removed and the marker plate is covered with gravel. The well is on an active disposal pad but there are no open reserve pits at this location. AOGCC inspectors were present during portions of the plugging of the well and Inspector Bob Noble was on site the day the marker plate was welded to the casing. Please call if you have questions or require additional information. Mike Bill BP Alaska Wells Well Integrity Group 907-564-4692 Office 907-564-4399 Fax 6/6/2012 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APR 17 2012 A r%r%r 0% WELL COMPLETION OR RECOMPL TtW ORT AND 1 a. Well Status: ❑Oil ❑Gas ❑ SPLUG ❑Other 'Abando d Suspended 1 b. Well Class: / 20AAC 25. 112�A<C 25.110 ❑ Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG WDSPL ❑ Other No. of Completions ero ® Service ❑ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 4/9/2012 12. Permit to Drill Number: 100-238 312-051 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 6/24/1973 13. API Number: 50-029-21817-00-00 4a. Location of Well (Governmental Section): Surface: 666' FNL, 1063' FEL, Sec. 11, T10N, R14E, UM Top of Productive Horizon: N/A Total Depth: 666' FNL, 1063' FEL, Sec. 11, T1 ON, R14E, UM 7. Date T.D. Reached: 6/26/1973 14. Well Name and Number: PBU OWDW-SW 8. KB (ft above MSL): 56.5' GL (ft above MSL): 15. Field /Pool (s): Prudhoe Bay Field / Undefined Pool 640036 9. Plug Back Depth (MD+TVD): 2134 2134 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 685950 y- 5939932 Zone- ASP4 TPI: x- y- Zone- Total Depth: x- 685950 y- 5939932 Zone- ASP4 10. Total Depth (MD+TVD): 2250 2250 16. Property Designation: ADL 028311 11. SSSV Depth (MD+TVD): None 17. Land Use Permit: 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1850' (Approx.) 18. Directional Survey: ❑ Yes ® No Submit electronic and printed information per 20 AAC 25.050 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): SP / DIL / 4 -Arm Caliper 22. Re-Drill/Lateral Top Window MD/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE AMOUNT CEMENTING RECORD PULLED - 13-3/8" 72# N-80 28' 100' 2 ' 100' -1/2" 17 7' 2215' 27' 221 -1/4" 3670 sx:Arctic 120 sx Arctic Set 24. Open to production or injection? ❑ Yes ® No If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): MD TVD MD TVD I� A 25. TUBING RECORD SIZE DEPTH SET MD PACKER SET MD /TVD 2-7/8", 6.5#, L-80 1941' 1920'/ 1920' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1978' Fill 1859' Weatherford Cement Retainer To Surface 363 sx Class 'G', 19 sx Arctic Set 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None 011JUMS APR 1.91011 d Form 10-407 Revised 12/2009 ! CONTINUED ON REVERSE t/ G' .11. ) •L �� /��/,,Submit Original Only - l /��-- • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. None Formation at Total Depth (Name): 31. List of Attachments: Summary of Work, Well Schematic Diagram my knowledge. 32. I hereby certify that th o oing i tr eITE=itle: I �� Signed: Joe Lastufk Drilling Technologist Date: PBU OWDW 100-238 312-051 Prepared By NameMumber. Joe Lastufka, 564-4091 Well Number Permit No. /Approval No. Drilling Engineer: Clint Spence 564-5111 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • CJ OWDW-SW, Well History Date Summary 03/04/12 T/I = 300/200. Temp = SI. T FL (pre P&A). Inj line removed. TBG FL @ surface. SV, WV, SSV, MV = Closed. IA = Closed. NOVP. 15:00 03/11/12 T/I = 140/120. Cement 3/8" circulating lines (2) from suface to 560' in IA. RU to first circulating line with triplex to establish injectivity. PT hose, good test. Start pumping diesel down line. IA pressuring up. Open IA to bleed trailer. Both IA and circ line bled down. Pumped approximately 6 gals of diesel at 2600 psi. Pump rate was approx 3 gpm. RU to 2nd circ line and pumped approx 6 gal of diesel @ 2400 psi. Pump rate was approx 3 gpm. SLB cement supervisor mixed up cement on location. RU Seal-tite's Haskel pump and pumped 1/4 gallon of gelled diesel and 2.75 gallons of Squeeze Crete cement down each circulating line. Pumped cement at approx .5 gpm at 1000 psi. RDMO. 03/11/12 T/1=0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL) PPPOT-T: Stung into test port (0+ psi), bled to 0 psi. Pumped through void, good returns. Pressured void to 5000 psi. for 30 min. test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Attempted to Pressure void to 2000 psi for 30 min. test. Test void pressure would only build to 800 psi. then Fluid began leaking out of Side outlet (cement circ port) in starting head. Bled void to 0 psi. Leaking stopped. Flange does not have LDS to energize primary seal. 03/12/12 '*'`WELL S/I ON ARRIVAL -"(P&A). TAGGED 2-7/8" XXN PLUG @ 1,906' SLM W/ 2.305" G -RING (No issues). EQUALIZED & Pul_LFD 2-7/8" XXN PLUG BODY FROM 1,928' MD.. TAGGED HARD BOTTOM @ 1,978' ELM W/ 2.00" G -RING (-2' of fill). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS 03/12/12 'WELL SHUT IN ON ARRIVAL' (ELINE TUBING PUNCH AND SET CEMENT RETAINER) INITIAL T/1/0= 470/0/0. RIH WITH MH -22/ CCL /2 WEIGHT BARS 43/MPD/ 5' TUBING PUNCHER/BOW SPRING TOOL LENGTH=27' TOOL WEIGHT =260 LBS FISHING NECK SIZE = 1.38" TUBING PUNCHED FROM 1875'- 1880' (5'@ 4 JSPF = 21 HOLES WITH MEDIUM CHARGES). CCL TO TOP SHOT 5', CCL STOP DEPTH AT 1870'. SSV AND SWAB VALVE CLOSED. DSO AND PE NOTIFIED OF DEPARTURE. FINAL T/IA/OA=510/0/0 03/13/12 "'JOB CONTINUED FROM 12 MARCH 2012"'(E -LINE TUBING PUNCHER -CEMENT RETAINER) INITIAL T/IA/OA=510/450/0. RIH WITH MH -22/2 EQF 43/CCUMDP/10' TUBING PUNCHER/BOW SPRING, TOOLSTRING OVERALL LENGTH 32', TOOL STRING WEIGHT 300#. FISHING NECK SIZE 1.38". CCL TO TOP SHOT DEPTH 5', STOP DEPTH AT 1841', PUNCHED INTERVAL 1846' TO 1856'. RIH WITH MH -22/2 EQF 43/CCUBAKER-05 SETTING TOOL/ WEATHERFORD CEMENT RETAINER, TOOLSTRING OVERALL LENGTH 31, TOOL STRING WEIGHT 250#. FISHING NECK SIZE 1.38". CCL TO TOP OF CEMENT RETAINER 10.77', TOP OF RETAINER SET AT 1859', CCL STOP DEPTH AT 1848.2'. WELL LEFT SHUT IN SWAB AND SSV CLOSED. PE AND DSO NOTIFIED OF DEPARTURE. FINIAL T/1/0= 350/450/0. JOB COMPLETE 03/13/12 T/I/O 150/230 Temp= SI CMIT-TxIA to 1500 psi (P & A) CMIT-TxIA PASSED to 1500 psi. Pump .3 bbls diesel to achieve test pressure. Tubing lost 48 psi, IA lost 48 psi in 1 st 15min. Tubing lost 0 psi, IA lost 8 psi in 2nd 15 min for a total loss of 48/56 psi over 30 min test. Bleed Tubing and IAP, approx .3 bbls. FWHP 150/230 SV,SSV=closed, MV=open, IA=open Page 1 of 3 • 11 OWDW-SW, Well History Date Summary 03/14/12 CTU #9 w/ 1.75" OD CT. Job Scope: P&A. Weather standby for ambient temperature to warm for Well Support to complete rig -up. AOGCC Inspector contacted for 24 hour notice and agreed to provide notification when beginning rig -up and a 3 hour call -out prior to test. EPA Inspector contacted and waived witnessed test. 03/17/12 Assist Well Support w/ pressure test ( P&A ) Road to location. Pre -heat diesel to 90* & assist w/ PT on hardline setup for CTU. 03/18/12 CTU #9 w/1.75" OD CT. Job Objective: P&A. Rig up and MU cement retainer stinger BHA: 2 3/16" MHA w/ 5/8" ball for disconnect, MU BHA 2.15" X -over, 1.93" X -over, 2.12" X -over, 1.688" FH Cement Retainer stinger. Total BHA length 8.59'. Max OD=2.188". Confirm TxIA communication by circulating 15 bbls to tanks. Stab into retainer and begin to pump for injection. Pump pressure increases and no injectivity. Unsting and begin to troubleshoot. 03/19/12 CTU #9 w/1.75" OD CT. Job Objective: P&A. Stung into cement retainer and unable to establish igjection up to 4000 psi. Contact town engineer and decide to pull to surface to inspect stinger. Stinger bonnet seals look good. Decided to PU WFD venturi to clean up the top of retainer. Made 2 runs w/ Venturi. Retrieved tea spoon volume junk. Conducted weekly BOP test, all test good. MU stinger nozzel BHA and RIH. 03/20/12 CTU #9 w/ 1.75" OD CT. Job Objective: P&A. <<< Continued from 19 March 2012 WSR >>> Made run with ported stinger to jet off the top of retainer. Run back w/ cement stinger and pump 25bbls of I 5.3ppq cement below retainer. Perform Bob Nobel with the state witnessed CMIT-IA to 1575psi. Passed. Then pumped 50 bbls of class G 15.8 ppg cement from surface to retainer and up the IA to surface . Jet thru IA valves w / biozan and freeze protect w / diesel . Jet across tree and BOP'S w / biozan and freeze protect tree. 03/27/12 T/1= 0/0. Temp= SI. State witness MIT -T to 1500 psi - PASSED & MIT -IA to 1500 psi - FAILED (Pre -State Witness) (Plug & Abandon). State Witness by Matthew Herrera. Mono -bore well. T & IA FL @ surface. Pumped 7 gals diesel down tubing to increased TP from 0 psi to 1662 psi in 5 minutes. In 15 minutes TP & IAP unchanged and in 2nd 15 minutes TP lost 2 psi, IAP unchanged for a total of 2 psi loss in 30 / minutes. Start MIT -IA to 1500 psi. Pumped 12 gals diesel down IA to stabilized and increased IAP from 0 ✓ psi to 1500 psi in 60 minutes. In 15 minutes IAP lost 100 psi and in 2nd 15 minutes IAP lost 70 psi. State Witness requested extending test additional 15 mins. In 3rd 15 mins IAP lost 55 psi and in 4th 15 mins IAP lost 0 psi for a total of 225 psi loss in 60 mins, TP increased 2 psi during test. See log for details. Final WHPs= 0/0. Job completed. SV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. 17:35 hrs 03/29/12 T/1= 3/0. Temp= SI. MIT -IA to 1500 psi - FAILED (Plug & Abandon). Mono -bore well. T & IA FL @ surface. Pumped 1.5 gals diesel down IA trying to stabilize IAP and perform MIT. Increased IAP from 0 psi to 1500 psi in 1 minutes. In 15 minutes IAP lost 310 psi and in 2nd 15 minutes IAP lost 100 psi. WIC requested extending test additional 30 mins. In 3rd 15 mins IAP lost 60 psi and in 4th 15 mins IAP lost 10 psi for a total of 480 psi loss in 60 mins. See log for details. Bled IAP back to 0 psi, 1 gal fluid returned. Final WHPs= 0/0. Job completed. SV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. 14:20 hrs 03/30/12 T/1=0/0. Temp= SI. Vac fluid from tree (Prep for P&A). Vac -truck removed approximately 5 gals of fluid from TBG. Measurement taking from top of tree cap to cement top in tubing measures 76 inches. SV,MV=closed. IA,OA=open to gauge. NOVP. 15:56 hrs. Page 2 of 3 L� • OWDW-SW, Well History Date Summary 03/31/12 T/1=0/0. WHPs (P&A). Rigged up crystal gauge on IA. SV=C. WV, SSV, MV=O. IA, OA=OTG. NOVP. 00:20. 04/02/12 T/I=NA/3. Temp=Sl. WHPs & Ck heater (P&A). Heater blowing hot, called for fueler. SV, WV, MV=NA. SSV=O. IA=OTG. NOVP. 01:00. 04/03/12 T/1= ONac. Temp= SI. CMIT-TxIA PASSED to 1500 Rsi (P&A). Mono bore well. Pumped —5 gals diesel down TBG and IA to reach test pressure. TP/IAP lost 133/129 psi during the 1 st 15 mins and 4/6 psi during the 2nd 15 mins for a total loss of 137/135 during the 30 min test. Bled TP and IAP to 0 psi (-2 gallons). Evacuated fluid from TBG down to top of cement. Final WHPs= 0/0. Job complete. SV, WV & MV= C. SSV= O. IA= OTG. NOVP. 14:00 04/04/12 /1= 0/0. Temp= SI. Rig up Wach Saw (P&A). Installed cellar containment. Rigged Wach saw to well head in preparation to cut well head. SV, SSV & MV= C. IA= OTG. NOVP. 16:00 04/05/12 T/1= 0/0. Temp= SI. Cut off well head (P&A). Opened up IA and tubing to atmosphere and started 30 minute no -flow test. Test passed. Rigged up crane to lifting cap and pulled approx 7400 lbs. Ran hose from vac truck into cellar. Started and tested Wachs saw. Engaed saw and started cut. Stopped saw approx half way through and installed wedges in cut. Continued with cut until complete. Cut wellhead off approx 3' below pad level. Total cutting time was 1.5 hour. Brought tree out of hole, set on pallet, rigged off saw and laid tree in containment. Sucked out fluids in tree with vac truck and called valve shop to pick up tree. RDMO. 04/06/12 Assist DHD w/ wiggle worm job. Pumped 14.3 bbls of hot fresh water. 04/07/12 T/I = 0/0. Cement 13 3/8" conductor from 28' to surface. Rigged up 31' of 1" pipe down casing. Hung pipe 3" off bottom. Rigged up SLB cement pump. Pumped —4 bbls of Arctic Set cement to fill casing. Washed up cement van and RD. 04/08/12 T/I = NA/NA. Temp = N/A. Assist Special Projects. Add approx 1.5 inches cement to conductor for top job. Job complete. 12:30 04/09/12 T/I = N/A, N/A. P & A. Installed and tack welded marker plate. AOGCC witness Bob Noble on location. Excavation crew buried well. Job complete. Page 3 of 3 TREE = 2-9/16" CW WELLHEh D = FMC ACTUATOR= 2-719- 13KR Fl PROD PKIR AB __1_111111 56 1 .51 1928 —f2-7/8- 3 1 2' KOP 0 Max Angle '-= "M6 — - 0 — - - - -- liiiium JD1PJC NOTE TREE CAP CONNECTION Datum , TVD= 110/03/10 mom 113-3/8"CSG, 72#,N -80,]D=12.347" Minimum ID = 2.205" @ 1928' 2-7/8" HES XN NIPPLE 718"TBG, 6.5#,L-60,EUE,.0058bpf10=2.441" 1-1 1941 PERFORATION SUMMARY REF LOG_ DIL ON 06125173 ANGLE AT TOP PERF: 0' @ 1989 gate: Refer to Production D8 for historical perf datz SIZE I SPF I INTERVAL I Opn/Sqz I SHOT I SQZ 1-11116"1 4 11980-20051 S I I Oil 9/06103120112 PBTD 1-1 2134' 5-1/2" CSG, 179, L-80, ID= 4.892" I 2215' F_TD -4 2250,' WETY NOTE OILY WASTE DISPOSAL WELL, CONTACT MIKE BILL PRIOR TO DOING ANY DOWNHOLE WORK . SOME LOGS ARE MEASURED FROM GROUND LEVEL, -2006 RWO-1 DEPTHS ARE REFERENCED TO RKB, RKB TO GL = 33—LOWER. FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY ** 3-1/2" OTIS TREE CAP CONNECTION 560' 13/8" CONTROL LINES, OPEN ENDED w /CHECK VLVS 1846' - 1856- H TBG PUNCH (03113/12) .2— 1859 — F-718- WFD CMT RETAINER (03113/12) 1875' - 1880' TBG PUNCH (03113112)] 1879 —2-7/8' _HES X NIP, ID = 2 313-� 1900' 1SEALLOCSUB,C0=2.4/0" 1901 BKR GBH-22—LOC SEAL ASSY , ID = 2370" 1902 2-719- 13KR Fl PROD PKIR ORIGINAL COM PLENON w / SEALBORE EXT, ID = 3,00 1928 —f2-7/8- HES XN NIP, ID = 2 205--1 , -L-�l 9 4 �1 —F2--718-- —VVL—EG, 1-0 _=—Z 441-7 -4_ELMD_L_0G_GE0 —(11/07/06 RST CDL) % 5v V\ [ 2070' 1 I DATE REV BY COMMENTS DATE I REV BY COMMENTS 06123173 ORIGINAL COM PLENON 03114112 JCM1JMD SET WFD & TBG PUNCH (0311311 01101185 RWO TTW1 PJC CEMIENT (031201112) 11/12106 D16 F?WO 10/22/07 JD1PJC NOTE TREE CAP CONNECTION 110/03/10 1 WEC/SV I SET TTP (0912811 G) 107/29/111 TAR/ PJC RESET XXN (7120/11) ITOP OF FILL (11/07/06) 1 PRUDHOE BAY UNIT WELL: OWDN-SW PERMIT No: 00-238 API No: 50.029-21817-00 SEC 11, Tl ON, R14E„ 1064 FEL, 668 FNIL BP Exploration (Alaska) 0 MEMORANDUM TO: Jim Regg e P.I. Supervisor �ij la FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL i State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 06, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC OWDW-SW PRUDHOE BAY UNIT OWDW-SW Src: Inspector Reviewed By: P.I. Supry '/- Comm Well Name PRUDHOE BAY UNIT OWDW- API Well Number 50-029-21817-00-00 Inspector Name: Matt Herrera SW 100-238-0 Permit Number: Inspection Date: 3/27/2012 p Insp Num: mitMFH120328211421 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well OwDw-sw Type Inj N, TVD 1902 IA 0 1500 1400 1330 1275 1275, TD 1002380 - Type Test SPT Test psi i 1500 OA nterval OTHER p/F F Tubing 11 12 13 14 14 14 Notes: MITIA for P&A 5trAhftf)JUN t 6 2212 Friday, April 06, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg _�,e?l ` 11tJ(v DATE: 4/9/2012 P. I. Supervisor FROM: Bob Noble SUBJECT: Suspended Well Cut-off Petroleum Inspector PBU OWDW-SW PTD 1002380 BP Exploration (Alaska), Inc. 4/6/12 1 received a call from BP representative Mel Iverson, telling me that he was in the process of jetting ice out of the conductor on PBU OWDW-SW with a hydro -blaster. I told Mel I was tied up on another job but I would be there as soon as I got freed up. I arrived on location about 3 hours later and met with the Mr. Iverson. The 13-3/8" by 5-'/2' � annulus was void of cement at surface. The 5-'/2" by 2-7/8" annulus and the 2-7/8" tubing were full of good hard cement. They were done Hydro -blasting down the conductor. Mel told me that they had gotten down to 28' and blasted there for an hour and it wouldn't go any farther. So they rigged it down and vac'd as much water out of the conductor out as they could. 4/7/12 1 went to location to witness the placement of cement into the conductor. I met with Mel again. They were rigging up 1" pipe to pump the cement down the conductor. The conductor was strapped and found bottom at 28'. Free water was found to be 4 feet from the bottom. The 1" tubing was run down the conductor so it was 3" off of the bottom. Schlumberger then rigged up their pump truck to the 1" tubing and pumped approximately 4 barrels of 15.7ppg Arctic Set 1 cement. A vac truck was used to vac up the first cement that came to surface; circulation continued until it looked like there was good cement to surface. 4/8/12 1 received a call from BP Rep Mel Iverson telling me that the cement had fallen back approximately 1 %2 feet in the conductor. I ask him to top it off and I would look at it tomorrow. 4/9/12 1 went to location to inspect the final cut-off. I met with Mel Iverson on location. All strings were found to be full of good hard cement. The marker plate was found to be the proper size and %" thick with the following information was bead welded onto it: BP Exploration Alaska Inc. OW DW-Sw� A�' 2012 PTD No. 100-238 API No. 50-029021817-00 The casing was cut-off 3' below the pad grade. The marker plate was tack welded on in 4 places. Attachments: photos (4) 2012-0409_Surface_Abandon_PBU_OWDW-S W_bn Pagel of 3 E Surface Abandonment — PBU OWDW-SW PTD 1002380 Photos by AOGCC Inspector B. Noble 4/7/2012 — 4/9/2012 • 2012-0409_Surface_Abandon_PBU _OWDW-S W_bn Page 2 of 3 PBU OWDW-SW Cutoff PBU OWDW-SW Cement to Surface in Conductor mmmm�'. Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, March 30, 2012 3:41 PM 3Cf To: 'Spence, Clint J'; Guy.Schwartz@Alaska.org Cc: Daniel, Ryan; Aivano, Michael J (ANC); Bill, Michael L (ASRC); Cismoski, Doug A Subject: RE: OWDW-SW PA Proposal State ver2 Proposal as revised is approved. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 *WED'AP(� ;: r �) �I `0 [. From: Spence, Clint J [mailto:Clint.Spence bp.com] Sent: Friday, March 30, 2012 1:27 PM To: Regg, James B (DOA); Guy.Schwartz@Alaska.org Cc: Daniel, Ryan; Aivano, Michael J (ANC); Bill, Michael L (ASRC); Cismoski, Doug A Subject: OWDW-SW PA Proposal State ver2 <<OWDW-SW PA_Proposal_State_ver2.ZIP>> All, Attached is the amended procedure as discussed for OWDW-SW suspension work. We have deleted line 7 in the program. With your approval we will continue on with the remaining program steps. Thank You Clint Spence AK Well Intervention Engineering Team Lead Office: 564-5709 Cell: 307-752-4771 Summary of Proposed Work BP Exploration Alaska Inc (BPXA) Suspension / P&A OWDW-SW PTD: 100-238 API: 50-029-21817-00 Prudhoe Bay Unit Oily Waste Disposal Well Southwest (OWDW-SW) is one of three EPA permitted Class I disposal wells located at Pad 3 near DS 6. The wells were originally drilled for a permafrost test in the mid 1970's and disposal began in 1976. The wells are perforated just below the permafrost at about 1980 feet. Two wells are normally active at one time with the third shut-in as a backup disposal well. In September 25, 2010, OWDW-SW failed an EPA witnessed MIT -IA and a subsequent leak detect log confirmed two tubing leaks at 850' and 1264' MD. There was no indication of a tubing leak prior to the MIT from routine annulus pressure monitoring. The well has remained shut-in with a plug in the tubing tail since. Borax -RST logging on September 24, 2010 showed an anomaly above the packer. Shut-in temperature logs run the same day did not confirm the anomaly. Repeat borax - RST, shut-in temperature and water flow logs were run July 16, 2011 to further diagnose the anomaly. Neither the repeat borax -RST nor the temperature logs showed the anomaly, but the water flow log showed slow movement in the anomaly area. An area of no fluid movement was observed between the perforations and the anomaly. Given the conflicting results, the logs failed to conclusively demonstrate that there is no vertical movement of fluids exterior to the casing. After reviewing the July 2011 logs and discussion with EPA, a Notice of Potential Non- compliance was forwarded to the EPA on August 19, 2011. The letter stated: "Given the conflicting results, these logs failed to conclusively demonstrate that there is no vertical movement of fluids exterior to the casing." BPXA does not see any viable repair options that would ensure the utility of the well. BPXA committed to P&A the well in the August 2011 letter. Well History OWDW-SW was drilled in 1973. 13-3/8" Conductor 12.25" hole drilled to 2250' 0 5-1/2" 17# casing cemented with 3670 sx of Arctic Set Cement 0 120 sx Arctic Set Cement was used as a top job. o Cement Bond Logs in 1973, 1974, and 1975 were run confirming cement behind the 5-1/2" casing. Perforated injection interval 1980 - 2005 ft. • Injection began in 1985 after running 2-3/8" 4.7# tubing. • UIC Class I disposal well permits issued in 1989, consolidated into a single permit in 1995. • Corroded tubing was replaced during a 2006 rig workover. Installed 2-7/8" 6.5# tubing to 1941 ft mdRKB with production packer at 1901 ft mdRKB Scope of Work The plan for OWDW-SW is to set a cement retainer in the tubing just above the packer and squeeze approximately 25 bbls of Class G cement below into the injection interval. The wellbore then will be filled Class G cement by circulating from surface through tubing punches just above the cement retainer. The wellhead will be cut off just at or slightly below pad level and a marker plate installed. This will leave the well as suspended as per AOGCC definitions, final cut on the well at the required 4 foot below tundra will take place at the time of pad remediation. 1. Service valves on tree and wellhead. 2. Slickline to pull tubing tail plug set in XN Nipple at 1928 ft. Drift tubing and tag top of fill below tubing tail. 3. Pump into well to confirm injection into perforated interval. Pump cement into dual 3/8" control lines to plug off. 4. Eline to punch tubing above and below the packer. Set cement retainer just above production packer and below upper set of tubing punches. Pressure test against cement retainer to confirm set and confirm circulation from tubing to tubing by casing annulus through tubing punches. 5. Coil tubing to stab into cement retainer and pump 25 bbls of Class G cement into perforated interval. Unsting from cement retainer and pressure test to 1500 psi. AOGCC & EPA witness pressure test. 6. Circulate cement down tubing and up tubing by casing annulus, 50 bbls of Class G cement. (10 % over hole volume) 7. This step has been deleted. 8. Remove tree, excavate around wellhead as necessary to allow access for wellhead removal and cut off wellhead just even with pad level. Top off cement in annuli as necessary. AOGCC & EPA witness cement top. 9. Tack weld on marker plate with following. AOGCC & EPA witness install of marker plate and info. At this point, the well will be suspended as per AOGCC definitions. The well will be cut off 4 foot below tundra level and the marker plate will be fully welded on at time of pad remediation. BP Exploration Alaska, Inc OWDW-SW API No. 50-029-21817-00 PTD No. 100-238 2 0 Current Wellbore Diagram MEE 2-9116" CW ANGLE AT TOP PERF: 0 @ 1980' W ELLHEAD=FMC Existing Cornent ACTUAi I OR'- jArctic Pack I Crude E= � JjAddd BF ELrnEV 32' Cement Send Fit 0 ,baIarn TVD Minimum ID = 2.205" @ 1928' 12-718" HES XN NIPPLE ---j 12-7/8'TBG, 6.5#,L-80,EtiE,.0058bpf,ID--2.441' I PERFORATION SUMMARY REF LOG: DL ON 06/2613 ANGLE AT TOP PERF: 0 @ 1980' Notei Refer to Roduction DO for hstodcal perf data MUM E= [whom Emm 15-1/2"CSG,1ML-�80JD=4.892- I SAFETY NOTE OLY WASTEDISPOSAL WELL. CONTACT MKE BLL PRIOR TO DONG ANY DOWNHOLEWORK - SOME LOGS AREVEASURED FK0MGF"(.MLEVEL. -2006RV40: CEPrHSARE REFFR94CED TO RCB, RKS TO GL = 33 -LOWER FLA NGE ON CSG SPOOL IS RATED TO 20110 PSI ONLY - 3-102" OTIS TREE CAP CONNECTION JSEALL2aS 6KR GBFI-22 LOC SEAL ASSY, 9! = 2370--j 5MADEM 1928 H 2.7V HES XN NP, ID = 2,205' WLEG, ID = 2A41' Tag TD at 1979 It and GL E -Line Jul 16, 2011 PRUCHOE BAY UNCT WELL: OWDW-SW PEFMT No: 00-238 APIKb: -1,0-029-21817-00 11, TION. R1 4F- 1064 FEL, 668 FN - BP Exploration (Alaska) 3 low= m MUM E= [whom Emm PRUCHOE BAY UNCT WELL: OWDW-SW PEFMT No: 00-238 APIKb: -1,0-029-21817-00 11, TION. R1 4F- 1064 FEL, 668 FN - BP Exploration (Alaska) 3 0 Proposed Wellbore Diagram TREE 2-9116' ClW WELLHEAD LC!UATQR � SIZE KS. ELEV - C)pn,'Sqz DATE 1-1 V16' 4 M,IX Arq6 0 bai MID,= urnTVb—=,-, F0 liomwW410 , ffiwjmluijn�� Tbg Punoh 1846-1855 ft ELMD - Cart retainer set at 1860 ft ELMD Tbg Punch 1874-1879 ft ELMD 12.7,'8'TBG, 6-59,L-80,EUiE�.0058bpf,D--2-441- I PERFORATCN SUMMARY REF LOG OIL ON 0612 SO 3 ANGLE AT TOP PERF: 0# 1980' f,bte: Refer to Froductiori DB for hstorical pert data SIZE TSPF NT AL C)pn,'Sqz DATE 1-1 V16' 4 1980 - 2005 0 1011 9M6 BXR GaH-22 LOC SEAL ASSY, 10 2,,7)8' 8 KR F1 PSDD FKR w I SEALeORE EXT, ID = 3.00 2-7/6' HE$ XN NP. ID = 2.205" HR -MD LOGGED (11 (07)06 RST/ CDD —1979 ft and GL - Tag TD Jul 16 2011 with E -Line 20-30 bbis of ','mt Se,jz'd n to Flerfs PRIJCHOE SAY UNIT WELL: OVODW-SW PERMfT No: 00-238 APfW: 50-029.21817-00 SEC ii,TION, 814F, 1064 FEL, 666 FNL BP Exploration (Alaska) 4 •EMMM P, MWENWOMMIMEMMOIll PRIJCHOE SAY UNIT WELL: OVODW-SW PERMfT No: 00-238 APfW: 50-029.21817-00 SEC ii,TION, 814F, 1064 FEL, 666 FNL BP Exploration (Alaska) 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, March 29, 2012 To: Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION (ALASKA) INC OWDW-SW FROM: Matt Herrera PRUDHOE BAY UNIT OWDW-SW Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry V" -- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT OWDW- API Well Number 50-029-21817-00-00 Inspector Name: Matt Herrera SW 100-238-0 Permit Number: Ins 3/27/2012 Inspection Date: Insp Num: mitMFH120328204055 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well OWDW-SW'Type Inj N VD 1902 IA 0 0 0 0 TD 1o0zsao (Type Test SPT Test psi 1500 OA 1660 Interval OTHER P/F P Tubing 9 1662 1662 i Notes: MITT for P&A StA-D JUN E Thursday, March 29, 2012 Page I of I 0 W't C9 vi s'vJ P74\ ccs Regg, James B (DOA) &--IOU From: Regg, James B (DOA) Sent: Thursday, March 29, 2012 5:55 PM �1 Z`Zr�v To: Daniel, Ryan Cc: Bill, Michael L (ASRC); Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: OWDW-SW (PTD 100-238) I think that is a better approach. For whatever its worth, you have already performed passing pressure tests to at least 1000psi on several occasions during past days. Time to get this well buttoned up. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Daniel, Ryan [mailto:Ryan.Daniel @bp.com] Sent: Thursday, March 29, 2012 3:57 PM To: Regg, James B (DOA) Cc: Bill, Michael L (ASRC) Subject: OWDW-SW (PTD 100-238) Jim, AMAF; err ?.0 Please let me know if you are in concurrence with the draft program changes below for OWDW-SW (PTD 100-238) following the MIT results today. Draft Plan forward with OWDW-SW • BP to submit a revised program for Sundry approval, effectively removing bullet point 7 in the work program requirement for a surface plug MIT (AOGCC reg's do not require this test on surface) • BP will remove wellhead and perform a Top cement job as applicable on the IA and TBG once we determine the fall back/volumes etc. Thanks Ryan/ Mike Bill Alaska `Wehs Intafsrity Team Leader 74P 1 !4') fniu bikl r: 114II ,€t,t�I'�1 0 Regg, James B (DOA) opat cwbw- sl,j From: Regg, Jamesa'16 (DOA) 117f � Sent: Wednesday, arch 28, 2012 1:58 PM ` 77 To: AK, D&C Well Integrity Coordinator Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: OWDW-SW (PTD #1002380) MITs Post P&A Redo MITIA; procedure calls for 1500 psi test. Report indicates lost more than 10 percent of test pressure (lost 170 psi after 30 minutes), and since initial test was 1500 psi, any pressure loss would fail AOGCC acceptance criteria. Refer to Industry Guidance Bulletin 10-004 Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWellIntegrityCoordinatora- bp.com] Sent: Wednesday, March 28, 2012 1:16 PM To: Regg, James B (DOA) Subject: OWDW-SW (PTD #1002380) MITs Post P&A Jim, Attached is the MIT form for OWDW-SW (PTD #1002380) AOGCC witnessed MIT -T and MIT -IA performed on 03/27/2012. The tests were witnessed by AOGCC representative Mr. Matt Herrera. <<MIT PBU OWDW-SW 03-27-12.xls>> Thank you, Mehreen Vazir Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator@BP.com 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: ,jim.rego(a-Waska.aov: doa.aogcc.prudhoe.bav@alaska.gov: phoebe.brooks@alaska.gov; tom.maunder(aalaska.gov OPERATOR: BP Exploration (Alaska), Inc. U, FIELD / UNIT / PAD: Pruo dh a Ba / PBU / OWDW t DATE: OPERATOR REP: AOGCC REP: y 03/27/12 Mehreen Vazir Matt Herrera TYPE INJ Codes TYPE TEST Codes D = Drilling Waste Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. R = Internal Radioactive Tracer Survey Well OWDW-SW I Type In'. I N TVD ' 1,902' Tubing 7 - 1662 1662 1660 • Interval 0 P.T.D. 1 1002380 '- I Type test I P Test psi 1500 Casing P/F P Notes: MIT -T for P&A Pumped 7 gals of diesel OA Well OWDW-SW Type In'. I N TVD 1,902' Tubing 10 12 13 14 14 14 Interval 0 P.T.D. 1002380 Type test P Test psi 1500 Casin 1,500 1,400 1,330 1,275 1,275 P/F P Notes: MIT -IA for P&A Pumped 12 Rals of diesel OA Well Type In'. N TVD Tubing Interval P.T.D. I Type test P Test psi Casin P/F Notes: OA Well I Type In'. TVD in Interval P.T.D. Type test Test psi ECain P/F Notes: OA Well I Type Ini.1 TVD Tubing Interval P.T.D.1 Type test Test psi Casin P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test Form 10-426 (Revised 06/2010) MIT PBU OWDW-SW 03-27-12 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) M.yrT-A Sits � �JQ'.SSvv� (cXs 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� � 2I DATE: 3/20/2012 P. I. Supervisor FROM: Bob Noble SUBJECT: Plug Test Petroleum Inspector BPXA PBU OWDW-SW PTD 1002380 - 3/20/2012 1 received a call from BPXA representative Larry Imm to witness a pressure test on the bottom plug on PBU OWSW-SW. The well is a UIC Class I disposal well operating under EPA permit AK11004-B. The plug was part of BPXA's effort to prepare the well for final abandonment which will be completed at a later date. Prior to my arrival, the following steps were completed: - A cement retainer had been set with E -line at 1928 ft; - Tubing holes were punched at 1850 ft; - Coil tubing was stung into the retainer and 25 bbls of 15.3 ppg Class G cement were pumped into the disposal perforations below the retainer. The procedure called for a 15 minute pressure test to 1500 psi, with the requirement to not lose more than 10% of the applied pressure. I held the test for an extra 15 minutes for additional information. The results of the test were: Pre Tubing = 0 psi; Annulus = 0 psi Initial Tubing = 1575 psi; Annulus = 1566 psi; allowable pressure loss 157 psi) 15 min Tubing = 1457 psi (lost 118 psi); Annulus = 1458 psi (lost 108 psi) 30 min Tubing = 1389 psi (lost 68 psi); Annulus = 1390 psi (lost 68 psi) Attachments: none , copy: Thor Culter, EPA Region 10 2012-0320_P1ug_PBU_0SD W -S W_bn EO 8�, A NNEV(0AP P:^ 7 2012 Certified Mail # 7008 3230 0000 2496 3870 February 13, 2012 Mr. Peter Contreras UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Re: Prudhoe Bay Unit Pad 3 Disposal Facility Request for Approval of Well Abandonment: UIC Class I Permit Plan AK -1 1004-B Dear Mr. Contreras: IK BP Exploration (Alaska) Inc. P.O. Box 196612 900 East Benson Boulevard Anchorage, Alaska 99519-6612 USA RECEIVED Alaska Cil & Gas Cons. Commission Anchorage e66~�A,3-`g 0Wtw SW BP Exploration (Alaska) Inc. (BPXA), operator of the Prudhoe Bay Unit Pad 3 Class I disposal facility, notified EPA on August 19, 2011 of plans to plug and abandon disposal well OWDW-SW by March 31, 2012. This letter is to submit, and request approval of, the current Plug and Abandonment Plan, EPA UIC form 7520-14 for this well. This plug and abandonment (P&A) plan contains a modified procedure from the plan submitted with the June 2009 Pad 3 UIC Class I permit renewal application, referenced in Part I, F.2 of permit AK -11004-B. The modified procedure uses coiled tubing to pump cement through a cement retainer as the first stage of the abandonment. The second stage involves perforating the tubing and circulating cement to surface in both the tubing and the annulus. The end result is essentially the same as the original plan, with the entire wellbore filled with cement. Enclosed also is the approval received from the Alaska Oil and Gas Conservation Commission (AOGCC) for this work. You will note that the AOGCC approval is to "suspend" the well. AOGCC site clearance regulations require cement to surface in all abandoned well annuli, all casings to be cut off at least three feet below original ground level and a marker plate welded to the outermost casing sting. Due to the close well spacing at this location, BPXA proposed to complete the downhole portion of the P&A and to initially cut off all casing strings at or below pad level with the marker plate installed. The final step to remove the casing strings below original ground level will be deferred until sometime in the future. The well will be classified by AOGCC as "suspended" until the final step is completed. BP believes this plan meets the intent of EPA UIC regulations for isolation contained in 40 CFR 144 and 146. Prior to issuing the Class I permit, EPA determined there are no underground sources of drinking water beneath the Pad 3 area. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. 0 9 If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, _e -- -11t�- Katharine Fontaine Logistics and Infrastructure Manager Attachments cc: Thor Cutler, EPA Region 10 Jim Regg, AOGCC Shawn Stokes, ADEC 0 9 OMB No. 2040-0042 Approval Expires 12/31/2011 United States Environmental Protection Agency NEPA Washington, DC 20460 PLUGGING AND ABANDONMENT PLAN Name and Address of Facility Name and Address of Ownartoperator ,c/o Environmental Advisor, Central, Mail Stop 42, BP Exploration iBP Exploration (Alaska) Inc. P.O.96612, Anchorage, AK (Alaska) Inc. P.O.Box 196612, Anchorage, AK 99516-6612 99516-6612 W Locate Well and Outline Unit on Section Plat -640 Acres N State I County _ Permit Number Alaska North Slope Borough AK 11004-B Surface Location Description S1t/'• 1/4 of NE -114 of AL 114 of 114 of Section 1 I ,Township. 0 : Range 14 Locate well In two directions from nearest lines of quarter section and drilling unit Surface Location 668 ft. Inn (NIS) -N Line of quarter section and/w, ft. from (EIW):E ! Lina of quarter section. TYPE OF AUTHORIZATION WELL ACTIVITY E y f L PLUG #2 CLASS I Size of Hole or Pipe In which Plug Will Be Placed (inch@ Area Permit 1_L1_ 1_L1_ Depth to Bottom of Tubing or Drill Pipe (ft (� Rule 1_L1_ 1_L1_ State I County _ Permit Number Alaska North Slope Borough AK 11004-B Surface Location Description S1t/'• 1/4 of NE -114 of AL 114 of 114 of Section 1 I ,Township. 0 : Range 14 Locate well In two directions from nearest lines of quarter section and drilling unit Surface Location 668 ft. Inn (NIS) -N Line of quarter section and/w, ft. from (EIW):E ! Lina of quarter section. TYPE OF AUTHORIZATION WELL ACTIVITY E F1 individual Permit PLUG #2 CLASS I Size of Hole or Pipe In which Plug Will Be Placed (inch@ Area Permit 5-1/2 n CLASS 11 Depth to Bottom of Tubing or Drill Pipe (ft (� Rule 1860 17 Brine Disposal Sacks of Cement To Be Used (each plug) Number of Wells ? 1 Enhanced Recovery Slurry Volume To Be Pumped (cu. ft.l 140 281 II Hydrocarbon Storage Calculated Top of Plug (ft.) 1860 0 CLASS III S 'Prushoe Bay UnitADL 028311 OWDW-SW Lease Name Well Number CASING AND TUBING RECORD AFTER PLUGGING METHOD OF EMPLACEMENT OF CEMENT PLUGS SIZE WT (LB/FT) TO BE PUT IN WELL (FT) TO BE LEFT IN WELL (FT) HOLE SIZE !__I The Balance Method 5-1/2 17 2215 12-1/4 ❑ The Dump Bailer Method 2-718 6.5 1941 ❑ The Two -Plug Method QOther COIL -ED Tus«Gi $k#.I.HZA0 C ixcLcL ATE CEMENTING TO PLUG AND ABANDON DATA: PLUG #1 PLUG #2 PLUG #3 PLUG #4 PLUG #5 PLUG iM PLUG #T Size of Hole or Pipe In which Plug Will Be Placed (inch@ 5-1/2 5-1/2 Depth to Bottom of Tubing or Drill Pipe (ft 1980 1860 Sacks of Cement To Be Used (each plug) Slurry Volume To Be Pumped (cu. ft.l 140 281 Calculated Top of Plug (ft.) 1860 0 Measured Top of Plug (if tagged ft.; Slurry Wt. (Lb./Gal.) 15.3 1 15.8 Type Cement or Other Material (Class 111) Class G I Class G LIST ALL OPEN HOLE AND/OR PERFORATED INTERVALS AND INTERVALS WHERE CASING WILL BE VARIED (If any) From I To I From I To 1 1980 1 2005 1 1 —1 Wells 5300,000 Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals Immediately responsible for obtaining the Information, i believe that the Information Is true, accurate, and complete. I am aware that there are significant penalties for submitting false Information, including the possibility of fine and Imprisonment. (Ret. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed Katharine Fontaine, Logistics & Infrastructure Manager Q-//3I/Z Summary of Proposed Work BP Exploration Alaska Inc (BPXA) Suspension t P&A QWDW-SW PTD: 100-238 API: 50-029-21817-00 Prudhoe Bay Unit Oily Waste Disposal Well Southwest (4WDW-SW) is one of three EPA permitted Class I disposal wells located at Pad 3 near DS 6. The wells were originally drilled for a permafrost test in the mid 1970's and disposal began in 1976. The wells are perforated just below the permafrost at about 1980 feet. Two wells are normally active at one time with the third shut-in as a backup disposal well. In September 25, 2010, 4WDW-SW failed an EPA witnessed MIT -IA and a subsequent leak detect log confirmed two tubing leaks at 850' and 1264' MD. There was no indication of a tubing leak prior to the MIT from routine annulus pressure monitoring. The well has remained shut-in with a plug in the tubing tail since. Borax -RST logging on September 24, 2010 showed an anomaly above the packer. Shut-in temperature logs run the same day did not confirm the anomaly. Repeat borax - RST, shut-in temperature and water flow logs were run July 16, 2011 to further diagnose the anomaly. Neither the repeat borax -RST nor the temperature logs showed the anomaly, but the water flow log showed slow movement in the anomaly area. An area of no fluid movement was observed between the perforations and the anomaly. After reviewing the July 2011 logs and discussion with EPA, a Notice of Potential Non- compliance was forwarded to the EPA on August 19, 2011. The letter stated: "Given the conflicting results, these logs failed to conclusively demonstrate that there is no vertical movement of fluids exterior to the casing." BPXA does not see any viable repair options that would ensure the utility of the well. BPXA committed to P&A the well in the August 2011 letter. Well Histonr OWDW-SW was drilled in 1973. • 13-3/8" Conductor • 12.25" hole drilled to 2250' 0 5-1/2" 17# casing cemented with 3670 sx of Arctic Set Cement 0 120 sx Arctic Set Cement was used as a top job. a Cement Bond Logs in 1973, 1974, and 1975 were run confirming cement behind the 5-1/2" casing. • Perforated injection interval 1980 - 2005 ft. • Injection began in 1985 after running 2-318" 4.7# tubing. • UIC Class I disposal well permits issued in 1989, consolidated into a single permit in 1995. • Corroded tubing was replaced during a 2006 rig workover. Installed 2-7/8" 6.5# tubing to 1941 ft mdRKB with production packer at 1901 ft mdRKB Scope of Work The plan for OWDW-SW is to set a cement retainer in the tubing just above the packer and squeeze approximately 25 bbls of Class G cement below into the injection interval. The wellbore then will be filled Class G cement by circulating from surface through tubing punches just above the cement retainer. The wellhead will be cut off just at or slightly below pad level and a marker plate installed. This will leave the well as suspended as per AOGCC definitions, final cut on the well at the required 4 foot below tundra will take place at the time of pad remediation. 1. Service valves on tree and wellhead. 2. Slickline to pull tubing tail plug set in XN Nipple at 1928 ft. Drift tubing and tag top of fill below tubing tail. 3. Pump into well to confirm injection into perforated interval. Pump cement into dual 3/8" control lines to plug off. 4. Eline to punch tubing above and below the packer. Set cement retainer just above production packer and below upper set of tubing punches. Pressure test against cement retainer to confirm set and confirm circulation from tubing to tubing by casing annulus through tubing punches. 5. Coil tubing to stab into cement retainer and pump 25 bbls of Class G cement into perforated interval. Unsting from cement retainer and pressure test to 1500 psi. AOGCC & EPA witness pressure test. 6. Circulate cement down tubing and up tubing by casing annulus, 50 bbls of Class G cement. (10 % over hole volume) 7. Wait on Cement 3 days. MIT -T and MIT -IA to 1500 psi. AOGCC & EPA witness pressure test. 8. Remove tree, excavate around wellhead as necessary to allow access for wellhead removal and cut off wellhead just even with pad level. Top off cement in annuli as necessary. AOGCC & EPA witness cement top. 9. Tack weld on marker plate with following. AOGCC & EPA witness install of marker plate and info. At this point, the well will be suspended as per AOGCC definitions. The well will be cut off 4 foot below tundra level and the marker plate will be fully welded on at time of pad remediation. BP Exploration Alaska, Inc OWOW-SW API No. 50-029-21817-00 PTD No. 00-238 2 0 Current Wellbore Diagram I K== t -w io t,nv WELLHtAU = tMC ACTUATOR= ANGLEAT TOPPERF 0@1980' KB EL W = 565, BF ELW - 32' KOP= 0 Max Angle = 0 Datun MID = 0 Sand' Pit Dalun TVD = rAPJPJC.fESETXXN(7)2fV11) t3 3 .$. Geri 1211 N 9" ':C - .._M; h 10, Minimum ID = 2.205" @ 1928' 2-718" HES XN NIPPLE 12-7/8' TBG, 6 5N L-80, EUE, .0058 bpf, D --2 441' 1 PG.RFORATION SL*"RY REF LOG: DL ON 06;25,73 ANGLEAT TOPPERF 0@1980' Ex4stral Cement SAFETY NOTE: OLY WASTE DISPOSAL WELL SPF '•'A a=: - rai; Pak ; Crude O W D S W COWBLL PRIOR TODOING DOWNHONHO LE W WORK . SOME LOGSS ARE MEASUREDF*}Added DATE Ccrnenl FROM GROUND LEVEL -2006 RVVO: CEPTHSARE 1980-2005 0 Sand' Pit REFERBVCED TO RKS, RKS TO GL = 33' "'LOWER FLANGE ON CSG SPOOL IS RA T® TO 2000 PSI rAPJPJC.fESETXXN(7)2fV11) 10;19/06 RDBIPAC SAIVBACK/CMT CAP ONLY " 3-112' OT1S TREE CAP CONNECTION t3 3 .$. Geri 1211 N 9" ':C - .._M; h 10, Minimum ID = 2.205" @ 1928' 2-718" HES XN NIPPLE 12-7/8' TBG, 6 5N L-80, EUE, .0058 bpf, D --2 441' 1 PG.RFORATION SL*"RY REF LOG: DL ON 06;25,73 ANGLEAT TOPPERF 0@1980' Note: Refer to Roducton DB for Nstcrical part data SIZE SPF INTERVAL OpnlSgz DATE 1-11/16` 4 1980-2005 O '0;13106 15 '-21' 'I,96, ';Ii L'iti i(`-4,? 1 �5- 1:Q'7iWX LlcES, A tt4 th4Jk35 w /CHECK V LV S <T;'I#Sxr,f�.6=2363" �j 1900 1SFI,L LOC SUB, K) = 2.4' U --1 1901 HBKRi:4i3N22OX- SEAL ASSv C -23f0- FtV BY COMNU41S 2-7/8" BKRFI PROD FKR 12113106 _1902 w / SEA LBORE EXT. ID = 3 00 10/22r07 JEYPJC NOTE TREF CAPCONfECTION 1929 : 716' XXN FLUG(07/20111) WEC/SV SEr TTP(09/28/10) 192!3 :.: 7t8" An XN NI'. C = 2.2155' 7i8" WLEG, D = 2 441" ,A) LOGe_.E—n i ' '; WO -k Tag TD at 1979 ft and GL E -Line Jul 16, 2011 DATE REV BY CONVENTS OATS FtV BY COMNU41S 06/23173 ORIGINAL COMPLETION 12113106 OR -G DRAFT CORRECTIONS 01/01/85 RWO 10/22r07 JEYPJC NOTE TREF CAPCONfECTION 11/12/06 016 RWO 101033/10 WEC/SV SEr TTP(09/28/10) 05131/06 DTM WELLHEAD CORRECTION 07;29111 rAPJPJC.fESETXXN(7)2fV11) 10;19/06 RDBIPAC SAIVBACK/CMT CAP JPA RIv1V SLJGGITS; PULL RUG ;16106 JW 3 L� Proposed Wellbore Diagram TREE= 2.9116 CMV SAFETY NOTE OLY WASTEDISPOSAL WELL. V 1,1,0'' -AU = i•t.Y; Existing Cement .iCiU<<-TOP, _ Arctic Pads 1 Crude KB. ELE/ = .Added Cement t.;,P ELLV = t-11116" KOP= Sand F111 Max Angle = ? 1 10/19/08 Datum MD = Datum TVD = 11116/06 JMUPAG RNW SLt1GCfrS1 PULL PLUG 100 Minimum ID = 2.205" a@ 1928' 2-718" HES XN NIPPLE • Proposed B SAFETY NOTE OLY WASTEDISPOSAL WELL. OA/ D 1 S w Y� = CONTACT BLL PRIMP. TO DOING ANY DOWNHOLEWORK SOME LOGS ARE MEA SUR® SIZE SPF I INTERVAL Oon/Sgz I DATE t-11116" FROM GROUND LEVEL "2006 RWO: CEPTHS ARE REFERENCED TO RK0. RKB TO GL = 33' "LOWER 198V - 20Gb O 1 10/19/08 10/19105 PPF PA 3ANDHACK I CMT CAP 11116/06 JMUPAG RNW SLt1GCfrS1 PULL PLUG FLANGE ON CSG SPOOL IS RAT® TO 2000 PSI ONLY " 3-1 T OTIS TREE CAP CONNECTION PERFORATION SUMMARY REFLOG: DL ON 06/25173 ANGLEAT TOP PERF: 0 Q 1900' Note: Refer to Production DB for historical peri data SIZE SPF I INTERVAL Oon/Sgz I DATE t-11116" 4 198V - 20Gb O 1 10/19/08 1901 F3kR,�6H-i2>.00SEAL ASSY. 0-23/9' 1928 -- X';!, L, . 2 ,-1)E �aQB B_MD LOGGED If 1107106 RST! CDL} 1979 ft and GL - Tag TD Jul 16 2011 with E -Line DATE REV BY COMMENTS BY COMMENTS 06123173 ORIGINAL COMPLETION !" : DR.G DRAFT CORRECTIONS 01101185 RWO JC ^Kti-e: Ikki=Cit P C',(�NNE ]ON 11/12106 016 RWO W11AW SV SE( ITP(09r2tittt.; 05131/06 DTM 'NELLHtAU CORHEGl ON PJC !+SE T XXN(7C2Ut 11) 10/19105 PPF PA 3ANDHACK I CMT CAP 11116/06 JMUPAG RNW SLt1GCfrS1 PULL PLUG PRUCHOE BAY UNIT WILL: OWDW-SW PERMIT No: 00-236 API No: 50-029-21817-00 SEC 11, T1 ON, R1 4E 1064 FEL, 666 FNL BP Exploration (Alaska) 4 • 0 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAr 7r. 9An RECEIVED FEB 0 3 20I2 I 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Poolo Repair Welt❑ Change Apprihvsd Pr'Gg ` rhi �] Suspend ❑ PlugPedoretlons ❑ Perforate❑ Pull Tubing ITimeExtension❑ Operation Shutdown ❑ Rowlter Sump. Well ❑ Stimulate❑ Alter Casing ❑ ❑ " Other. 2. Operator Name. 4. Current Well Class: 5. Permit to Drill Number: SP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ Stratigraphio ❑ Service Q 100.2380 3. Address: P.O. Box 195812 8. API Number Anchorage, AK 94519.8812 50.029-21817-00-00 T. If perforating, closest approach In pool(s) opened by this operation M nearest 8. Wall Name and Number property lime where ownership or landownership changes: Spacing Exception Required? Yee ❑ No ❑ OWAW-SW 9. Property Designation (Lease Number): W. Field/Pool(s); ADLO-02831 f PRUDHOE BAY Field / UNDEFINED Pod 11. PRESENT WELL C014111TION SUMMAINY Total Dept11 MD (ft): Total Depth TVD (it): Effective Depth MD (ft): Effective Deptn TVD (ft): Plugs (measured): Junk (measured): 2250 2134 2250 2134 1928 NONE Cuing Length Site MD TVD swat Collapse Structural Conductor 72' 13-318" 72# L-80 28 100 28 100 4930 2670 Surface 2188' 5.112° 17# L-80 27 2215 27 2215 7740 8280 Intermediate Production Liner Perforation Depth MO (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: TTubling MD (ft): SEE ATTACHED - 2-718"6.5# L-80 24 1941 Packers and SSSV Tvoe: 2-718" Baker F-1 Packer Packers and SSSV MD and TVD (ftt: 1902 1902 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Opemlions Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q 14, Estimated Date for 15. Well Status after proposed work; Commencing Operations: 2MG12012 Oil ❑ Gere ❑ WIND ❑ GINJ ❑ WDSPL ❑ Suspended 2 WAG p Abandoned 0 16, Verbal Approval: Date: Commission Representative: GSTOR ❑ $PLUG ❑ 17. I hsmby certify that the foregoing is true and correct to the teat of my knowledge. Contact Clint Spence Printed NameCI Spenc Tide Well Intervention Team Lead Signature Phone Date 564-5111 2/2/2012 Prepared by Joe Lastufka 5"4091 COMM133ION USE ONLY Conditions of approval: Nolify Commission so that a representative may witness Sundry Number. 3 1 Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: le IV -+►is/# ..�s` tiS LA/t Subsequent Form Required: / O —it APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: `J Form 10403 Revised 1/2010 DUPLIC/I.T Jroo t[xrat in Duplicate I • • P. SEAN PARNELL, GOVERNOR AJ AsKA MOIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMSSIOK �¢ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Clint Spence Well Intervention Team Lead BP Exploration (Alaska), Inc. 3 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Undefined Pool, OWDW-SW Sundry Number: 312-051 Dear Mr. Spence: SLANNED FEB 1 6 2012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. VAR Sincerely, Daniel T. Seamount, Jr. Chair DATED this / day of February, 2012. Encl. ��/1 VY At s' STATE OF ALASKA 7.' ALAS L AND GAS CONSERVATION COMMISSI� APPLICATION FOR SUNDRY APPROV.4 20 AAC 25.280 RECEIVED i FEB 0 3 2012 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well El ` " ti. han ' r ;wr n FE�B/ 1 Suspend 2, Plug Perforations ❑ Perforate❑ Pull Tubing yy M 1G �Wi4e Extension Operation Shutdown ❑ Re-enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑ - 100-2380 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-21817-00-00 - 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: ❑ El OWDW-SW - Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028311- PRUDHOE BAY Field / UNDEFINED Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 2250 - 2134 2250 2134 1928 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 13-3/8" 72# L-80 28 100 28 100 4930 2670 Surface 2188' 5-1/2" 17# L-80 27 2215 27 2215 7740 6280 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 2-7/8" 6.5# L-80 24 1941 Packers and SSSV TVDe: 2-7/8" Baker F-1 Packer Packers and SSSV MD and TVD tft): 1902 1902 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory p Development ❑ Service 21- 1-14. 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/16/2012 Oil ❑ Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended - Q WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Clint Spence Printed Name lint ence Title Well Intervention Team Lead Signature Phone Date 564-5111 2/2/2012 Prepared by Joe Lastufka 564-4091 COMMISSION USE ONLY Sundry Number: /� 31 ?jam V Conditions of approval: Notify Commission so that a representative may witness Plug Integrity wr BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: /V A % o+; Subsequent Form Required: 6 — yD 7 APPROVED BY 4AM �7 G Approved by: COMMISSIONER THE COMMISSION Date: - Form -403 Revised 1/2010 /3 Submit in Duplicate TR NAI. OWDW-SW 100-238 PERF ATTAr41MFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Tol Tvd Depth Bas OWDW-SW 1/2/85 PER 1,980. 2,005. 1,980. 2,005. OWDW-SW 2/28/02 FIL 1,979. 2,134. 1,979. 2,134. OWDW-SW 10/15/06 SPS 1,989. 2,005. 1,989. 2,005. OWDW-SW 10/16/06 SPS 1,996. 1,989. 1,996. 1,989. OWDW-SW 10/17/06 SPS 1,992. 2,005. 1,992. 2,005. OWDW-SW 10/18/06 SPS 1,929. 2,005. 1,929. 2,005. OWDW-SW 11/6/06 SPR 1,929. 2,005. 1,929. 2,005. OWDW-SW 9/29/07 FIL 1,979. 2,005. 1,979. 2,005. OWDW-SW 9/29/10 BPS 1,928. 2,005. 1,928. 2,005. OWDW-SW 7/15/11 BPP 1,928. 2,005. 1,928. 2,005. OWDW-SW 7/20/11 BPS 1,928. 2,005. 1,928. 2,005. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 0 C� Summary of Proposed Work BP Exploration Alaska Inc (BPXA) Suspension / P&A OWDW-SW PTD: 100-238 API: 50-029-21817-00 Prudhoe Bay Unit Oily Waste Disposal Well -Southwest (OWDW-SW) is one of three EPA permitted Class I disposal wells located at Pad 3 near DS 6. The wells were originally drilled for a permafrost test in the mid 1970's and disposal began in 1976. The wells are perforated just below the permafrost at about 1980 feet. Two wells are normally active at one time with the third shut-in as a backup disposal well. In September 25, 2010, OWDW-SW failed an EPA witnessed MIT -IA and a subsequent leak detect log confirmed two tubing leaks at 850' and 1264' MD. There was no indication of a tubing leak prior to the MIT from routine annulus pressure monitoring. The well has remained shut-in with a plug in the tubing tail since. ✓ Borax -RST logging on September 24, 2010 showed an anomaly above the packer. Shut-in temperature logs run the same day did not confirm the anomaly. Repeat borax - RST, shut-in temperature and water flow logs were run July 16, 2011 to further diagnose the anomaly. Neither the repeat borax -RST nor the temperature logs showed the anomaly, but the water flow log showed slow movement in the anomaly area. An area of no fluid movement was observed between the perforations and the anomaly. After reviewing the July 2011 logs and discussion with EPA, a Notice of Potential Non- compliance was forwarded to the EPA on August 19, 2011. The letter stated: "Given the conflicting results, these logs failed to conclusively demonstrate that there is no vertical movement of fluids exterior to the casing." BPXA does not see any viable repair options that would ensure the utility of the well. BPXA committed to P&A the well in the August 2011 letter. Well History OWDW-SW was drilled in 1973. • 13-3/8" Conductor 12.25" hole drilled to 2250' 0 5-1/2" 17# casing cemented with 3670 sx of Arctic Set Cement 0 120 sx Arctic Set Cement was used as a top job. e/ o Cement Bond Logs in 1973, 1974, and 1975 were run confirming cement behind the 5-1/2" casing. Perforated injection interval 1980 - 2005 ft. • Injection began in 1985 after running 2-3/8" 4.7# tubing. • UIC Class I disposal well permits issued in 1989, consolidated into a single permit in 1995. • Corroded tubing was replaced during a 2006 rig workover. Installed 2-7/8" 6.5# tubing to 1941 ft mdRKB with production packer at 1901 ft mdRKB Scope of Work The plan for OWDW-SW is to set a cement retainer in the tubing just above the packer and squeeze approximately 25 bbls of Class G cement below into the injection interval. The wellbore then will be filled Class G cement by circulating from surface through tubing punches just above the cement retainer. The wellhead will be cut off just at or slightly below pad level and a marker plate installed. This will leave the well as suspended as per AOGCC definitions, final cut on the well at the required 4 foot below tundra will take place at the time of pad remediation. 1. Service valves on tree and wellhead. ✓ 2. Slickline to pull tubing tail plug set in XN Nipple at 1928 ft. Drift tubing and tag top of fill below tubing tail. r3. Pump into well to confirm injection into perforated interval. Pump cement into dual 3/8" control lines to plug off. 4. Eline to punch tubing aye and below the packer. Set cement retainer just above production packer and below upper set of tubing punches. Pressure test against cement retainer to confirm set and confirm circulation from tubing to tubing by casing annulus through tubing punches. 5. Coil tubing to stab into cement retainer and pump 25 bbls of Class G cement into perforated interval. Unsting from cement retainer and pressure test to 1500 psi. AOGCC & EPA witness pressure test. S%" . .aZSZ 6fe-11dt- 6. Circulate cement down tubing and up tubing by casing annulus, 50 bbls of Class G� cement. (10 % over hole volume) . d2.3 x M o, --yy 64L s 7. Wait on Cement 3 days. MIT -T and MIT -IA to 1500 psi. & EPA witnessS 4f"— pressure test. IkL•� .�� 8. Remove tree, excavate around wellhead as necessary to allow access for wellhead removal and cut off wellhead just even with pad level. Top off cement in annuli as necessary. AOGCC & EPA witness cement top. i/ 9. Tack weld on marker plate with following. AOGCC & EPA witness install of marker plate and info. At this point, the well will be suspended as per AOGCC definitions. The well will be cutoff 4 foot below tundra level and the marker plate will be fully 6(� welded on at time of pad remediation. BP Exploration Alaska, Inc OWDW-SW API No. 50-029-21817-00 PTD No. -100-238 OA 0 0 Current Wellbore Diagram TREE= 2.9/16" CMV ANGLE AT TOP PERF: 0 @ 1980' WELLHEAD= FMC Existing Cement ACTUATOR = I INTERVAL I Arctic Pads 1 Crude KB. F1E✓ = 56.5' Added Conant BF. ELE'V = 32' 10119!06 KOP= 0 © Sand Fit Max Angle = 0 Dot urn MID Datum TVD = 13-3/8" CSG, 72#. N-80. ID = 12.347" kr-1c Minimum ID = 2.205" @ 1928, 2-7/8" HES XN NIPPLE 12718" TBG, 6.54, L-80, EUE, .0058 bpf, D x.441' PERFORATION SUMMARY REF LOG: DL ON 06/25!73 ANGLE AT TOP PERF: 0 @ 1980' Wte: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I OpnlSgz DATE 1-11/16' 4 1980-2005 1 O 10119!06 SAFETY NOTE: OILY WASTE DISPOSAL WELL. CONTACT MIKE BLL PRIOR TO DOING ANY DOWNHOLE W ORK . SOME LOGS ARE MEA SUR® FROM GROUND LEVEL. -2006 RWO: DEPTHS ARE REFERENCED TO RKB, RKB TO GL = 3T —LOWER FLANGEON CSG SPOOL IS RAT® TO 2000 PSI ONLY " 3-112"OTS TREE CAP CONNECTION 318" CONTROL LINES, OPEN ENDED w /CHECK V LV S -718" HES X NIP. ID = 2.313" DATE REV BY COMMENTS 1900 SEAL LOC SUB, D = 2410- 06123173 ORIGINAL COMPLETION 1901 BKR GBK22 LOC SEAL ASSY, D = 01/01185 RWO 1902 2-718" BKR F1 PROD FKR 11/12106 D16 RWO w I SEALBORE EXT, ID = 3.00 05/31/06 DTM WELLHEAD CORRECTION 1928 2.718 XXNFtUG(07121111) 10/19/06 RDBIPAG SANDBACK 1 CMT CAP 1928 2- 718" HES XN NIP, ID = 2.205" 11;16.,'06 JMCIPAG RMV SLUGGITS 1 PULL PLUG 1941 2-718' VVLEG, D = 2.441" 1908 HEAc LOGGED (11107/06 RST,- CLL. Tag TD at 1979 ft and GL E -Line Jul 16, 2011 DATE REV BY COMMENTS DATE REV BY COMMENTS 06123173 ORIGINAL COMPLETION 12;13;06 BJMCJPJC DR -G DRAFTCORRECTIONS 01/01185 RWO 101227 JD"PJC NOTE: TREE CAPCONNECTION 11/12106 D16 RWO 10/03110 WECJSV SETTTP(09+28/10) 05/31/06 DTM WELLHEAD CORRECTION 07129/11 TARtPJC RESETXXN(712011) 10/19/06 RDBIPAG SANDBACK 1 CMT CAP 11;16.,'06 JMCIPAG RMV SLUGGITS 1 PULL PLUG PRUDHOE BAY UNIT WELL: OWDW-SW PERMIT No: 00-238 API No: 50-02921817-00 SEC 11, T10N, R14E� 1064 FEL, 668 FNL BP Exploration (Alaska) 3 0 0 Proposed Wellbore Diagram TREE = 2-906" CRN REF LOG: DL ON 06125/73 WELLHEAD = FMC Existing Cement ACTUATOR - I INTERVAL Arctic Pack I Crude KB. ELEY 56-5' 4 BF ELEV - gp Added Cement KC>P- J 0 Sand%Fill tvlux Angle - U Datsun MD = Datum TVD - 13-318" CSG, 72#, N-80, ID = 12.347" 1 C Minimum ID = 2.205" @ 1928' 2-718" HES XN NIPPLE Proposed B OWDW-SW Tbg Punch 1846-1855 ft ELMD Cmt retainer set at 1860 ft ELMD _-�- Tbg Punch 1874-1879 ft ELMD =CiFLiN PERFORATION SUMMARY REF LOG: DL ON 06125/73 ANGLE AT TOP PERF: 0 Q 1980' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn/Sqz DATE 1-11116" 4 1980-2005 O 10/19106 W SAFETY NOTE OLY WASTE DISPOSAL WELL. CONTACT MIKE BLL PRIOR TO DOING ANY DOWNHOLE WORK . SOME LOGS ARE MEASURED FROM GROUND LEVEL. ""2006 RWO: DEPTHS ARE REFERD CED TO RKB, RKB TO GL = 33' "'LOWER FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY - 3-117 OTLS TREE CAP CONNECTION OPEN ENDED w/CHECK V LV S 1879 2-718- HES X NIP, D = 2313- 1900 SEAL LOC SUB, D - 2.410' 1901 BKRGBH-22LOCSEALASSY,D= 1902 2-7,8" BKR Ft PROD WR wi SEAWORE EXT, ID -100 1928 H2-7/8' HES XN NIP ID - 1941 H2-718-WLEG,2=2.441- I 1908 BMD LOGGED (11107106 RST/ CDL ) -j —1979 ft and GL - Tag TD Jul 16 2011 with E -Line 20-30 bbls of Cmt Sgz'd in to Perfs DATE REV BY COMMENTS DATE REV BY COMMENTS 06;23173 ORIGINAL COMPLETION 12/13/06 BJMCJPJC DFLG DRA FT CORRECTIONS 01101/85 RWO 10122107 JOPJC NOTE: TREECAPCOMECTION 11/12/06 D16 RWO 10/03110 WFfJSV SErTTPj09/28110) 05/31/06 DTM WELLHEAD CORRECTION 07129,'11 TAR1PJC RESETXXN(71DY11'• 10/19/06 RDB/PAG SANDBACK I CMT CAP 11116;06 JMC+PAG RMV SLUGGITSI PULL PLUG PRUCHOE BAY UNIT WELL: OWDW-SW PERMIT No: 00-238 A PI No: 50.029.21817-00 SEC 11, T1 ON, R1 4F 1064 FEL; 668 FNL BP Exploration (Alaska) 4 t,77 7776 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Stephanie Pacillo well Job 9 Bio - 2.35 25 -JAN -2012 RECEIVED JAW -172 0 17, 5873 Company: State of Alaska Alaska Olt & Gas Cons Comm Ann: Christine Shartzer 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD G -11B BINC-00051 RESERVOIR SATURATION TOOL LOG 7 -Jul -11 1 1 K -05D BUTT -00010 MEMORY COMPENSATED NEUTRON LOG 26 -Aug -11 1 1 04-22AL1 SAUJ-00054 MEMORY COMPENSATED NEUTRON LOG 19 -Nov -10 1 1 J -22A BJGT-00049 RESERVOIR SATURATION TOOL LOG 6 -Jul -11 1 1 F -01A BINC-00049 RESERVOIR SATURATION TOOL LOG 5Jul-11 1 1 11-28A BRRJ-00017 RESERVOIR SATURATION TOOL LOG 27 -Oct -11 1 1 H-26 BJGT-00062 RESERVOIR SATURATION TOOL LOG 22 -Aug -1 I 1 1 07-13C BD88-00148 MEMORY COMPENSATED NEUTRON LOG 7 -Aug -11 1 1 F-30 BINC-0 0048 RESERVOIR SATURATION TOOL LOG 4 -Jul -11 1 1 H -04B BUTT -00033 MEMORY COMPENSATED NEUTRON LOG 6 -Oct -11 1 1 J-19 BINC-00057 RESERVOIR SATURATION TOOL LOG 13 -Aug -1 I 1 1 15-17 BVYC-00006 RESERVOIR SATURATION TOOL LOG 29 -Sep -1 I 1 1 M -21A BBSK-00074 RESERVOIR SATURATION TOOL LOG 6Jun-11 1 1 E -19C BD88-00132 MEMORY COMPENSATED NEUTRON LOG 6 -Jul -11 1 1 2-04/M-19 AV112-00100 RESERVOIR SATURATION TOOL LOG 9 -Aug -1 I 1 1 G-21 BG4H-00070 _ 'RESERVOIR SATURATION TOOL LOG 6 -Aug -11 1 1 04.23A BBSK-00091 RST SIGMA W/ BORAX 26 -Aug -1 I 1 1 OWDW-SW AV1P-00091 RESERVOIR SATURATION TOOL LOG 16Jul-11 1 1 1 TGtiL � 91 1 IIS PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND KETUKNING UNt COPY tAUM ,U: BP Exploration (Alaska) Inc. Petrotechnical Data Center 1-112-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 0 Is RECEIVED bp NOV 0 1 Zotl fig2 04 & Gas ConS. CoMiSSIon Certified Mail # 7011 0110 0000 Anchorage BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 October 28, 2011 (907) 561-5111 UIC Manager, Ground Water Protection Unit C U.S. Environmental Protection Agency (OCE -127) k 0 1200 Sixth Avenue, Suite 900 ' A� Seattle, WA 98101 — SVv `o U -a3R- RE: Third Quarter 2011 – Pad 3 Injection Well Monitoring Report UIC Class I Permit AK –11004-B Dear UIC Manager:�`lla This report is being submitted to fulfill the third quarter 2011 (July – September) reporting obligations for the above referenced permit. Enclosed are three forms [EPA 7520-8 (2-84)] containing the information required by Part 11, Section E of the permit. Also attached is a listing of the types and volumes of materials injected during the reporting period, a CD of the raw data, and graphs showing injection pressure, annular pressure, and injection volume for the wells. A description of the wastes managed at Pad 3 has been previously submitted to the EPA in the Waste Analysis Plan (WAP). The enclosed graphs and the raw data being submitted electronically on CD are a requirement under the Pad 3 UIC Permit (AK -1 1004-13). There are no permitted limits for the pH and temperature of the injected fluids. They are included in the reports as a physical description of the injected fluids (see Part II, Section E (1)(b) of the permit). The pH values define the non -hazardous range allowed for non- exempt fluids injected and the temperature values define the range historically encountered. A high well injection pressure reading was recorded during surveillance logging in OWDW-NW on July 18, 2011. The NW well was shut in at the time and no injection was taking place in the well. There were no excursions beyond the permit allowances this quarter. Several annual well surveillance activities were undertaken during the reporting period. These activities included tubing inspection logs in OWDW-NW and SE conducted on July 18 and 19, 2011; fluid movement tests in well OWDW-SW on July 16, 2011 and in well OWDW-SE and NW conducted on September 19 and 20, 2011; and annulus pressure tests in wells OWDW SE and NW conducted on September 21, 2011. The results of these tests and logs have been or will be forwarded in separate correspondence. I certify under penalty of law that I have personally examined, and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, believe that the information is true, accurate, and complete. I am aware that there are 9 • UIC Manager October 28, 2011 Page 2 significant penalties for submitting false information, including possibility of fine and imprisonment. If you need any clarification or additional information concerning these reports, please contact Alison Cooke, at (807) 564-4838 or Alison.Cooke @bp.com. Sincerely, —f-- K thy Fontain Logistics/Infrastructure Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2011 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum July August September 0 0 0 2 1 0 4 3 3 Injection Rate (GallMin) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 0 0 2 1 0 2 2 2 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 0 0 0 0 0 0 Temperature (F) 1. Minimum 2. Average 3. Maximum N/A N/A WA N/A N/A N/A N/A NIA NIA pH 1. Minimum 2. Average 3. Maximum NIA NIA WA N/A N/A N/A N/A NIA N/A Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 0 0 0 0 F-70 0 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SW Well ADEC 9821 - DB001 EPA Well Permit No. AK -11004A Name and Official Title Kathy Fontaine Infrast/Log Manager Signature Date Signed tP'A Form 7b"A" (Z-04) The values provided define the non - hazardous range and are not measured values . See Waste Analysts Plan. Values in parenitmeses ( ) are actual values for permit compliance. Pad 3 - Injection Composition Summary 0710112011 to 0913012011 By Component Component Acid Aqueous Solutions Arctic Pao Bilge Water Boiler Blowdown cellar box fluids Cement/Contaminate Chemclear Citri-Sweet-HD class 1 rinsate class 1 sump fluids class 2 dnsate class 2 rinsate Class 2 Sump Fluids Cothes Wash Water Crude Oil Cutfings D-600 Diesel Dlesel/Water Gel Domestic Water Drilling Mud Drum rinsate DT -3000 sze clear detergent fin fan foam fin fan soap Frac fluids freeze protect / down hole Fresh Water gel Printed on Tuesday, October 18, 2011 Forth Slope Technical Services Equipment Services Group Barrels 35.40 0.83 132.60 8.00 200.00 35.00 4,864.25 1.00 4.00 8,466.00 595.00 584,00 9,089.00 200.00 21.56 2,055.93 79.75 30.00 819.62 1,362.13 933.50 10,405.71 50.00 6.80 1.00 9.84 2.10 169.70 8.00 79,478.31 5.54 Page 1 of 3 Pad 3 - Injection Composition Summary 07/01/2011 to 09/30/2011 By Component Component geo vis Glyooi GravellSand ground water lathe coolant Ig crosslinker' Line pigging solids meg Methanol methanol water Mineral oil non haz soap non -hazardous fluids oil based mud Photo processor fluids pigging fluids Pigging Retums Pigging Sotkis pit water Ponded Water Produced Water rain water Rain/Storm water rainwater rainwater/snowmek remediation fluid Reserve/Flare/Relief Pit Water Rinsate SSG Scale/Corrosion Inhibitor Seawater/Brine/KCI w.w.caw,y�aasaa w.nn.,a�rtMxa. Printed on Tuesday, October 18, 2011 Notch Slope Technical Services Equipment Services Group Barrels 42.44 2,537.94 0.17 38.00 4.00 14.28 370.00 25.60 325.64 560.00 93.32 0.30 70.00 0.82 0.44 26.00 42.00 9.13 1,450.00 258.00 12,623.17 418.00 1,106.00 749.00 318.00 355.00 5,4.80.00 3,187.85 2.50 2.88 25,302.30 Page 2 of 3 Pad 3 - Injection Composition Summary 07/01/2011 to 09/30/2011 By Component Component seawater/methanol sewage snow melt snow meWponded water Snowmelt snowmelt(ponded water Soap Soda ash SPILL CLEANUP MATERIAL Spill Cleanup Waste storm water stormwater Sump fluids Turbine washwater ultra sonic wash fluid Used Oil washing machine water water Water Treatment Fluid well bore fluids well cellar fluids WRB Soap zyglo penetrant Total Volume: Printed on Tuesday, October 16, 2011 0 North Slope Technical Services Equipment Services Croup Barrett 580.00 2.00 928.89 137.00 3,154.60 190.00 5.10 18.00 984.00 883.00 3,111.50 954.00 3,834.88 9.00 101.00 0.11 120.00 134,40 1.00 20.00 2,174.00 11.20 0.12 192,396.96 Page 3 of 3 Total Well Volumes 80000 70000 60000 50000 40000 m 30000 20000 10000 0 NN NN INN NN NN NN NN NN NN NN NN .4111N� NN NN NN p 4P Orp & N\fp I I (P 0 41 p s , e\ , A\f ,\\N' A\ A \N 44P 4' 'X' NKIP Days .Total Volume Injected 0 I* a Maximum Injection Pressure 1600 1400 _. 1200- 1000 200 1000 -- A 471 800- 600--- 400 00 600 400 200 0 Rh R�'' RR �R RR RR ,�R RR RR RR RR RR RR RR RR ,��'` Days NW SW I --SE - - Limit j •, i a a Maximum Annular Pressure 160 140 120 100 80 60 40 20 __ ;,�.,.�..I► . �3�tio '�� 1t '�� 1� 1� •��'` 11'` AXN A`� -N -N\ti A< 11 1\01 Days 0 Total Well Volumes 80000 70000 60000 50000 40000 R 30000 20000 10000 0 —Total Volume Injected Ohl R�� �'�~ ii�� 'p+�'` Q�� X3411 t�A"` QNN 4�' �h`` ©�'` O^ti NN ©``~ O~'� N\C �-50�g�� ti��ry ti `s ���� 4�'�� $ 4 4 % 4 Days i Maximum Injection Pressure 1600 1400 1200 1000 a 800 600 400 200 P11 Zhh IRC �hh �hh �~\fp 4inif goeomcb\�'',�4hh t\ryhm ry'hh ���hh N\OAsh�`;ryO,` Im'4hhth�tithti~h 5h��4 Days 0 160 140 120 100 a 80 60 40 20 0 Maximum Annular Pressure 0 0 0 0eo� Days ?—NW • SW SE i I— Limit' • Total Well Volumes 50000 m ro 30000 20000 10000 i❑ NN NN N"- 'Nh N� N� NN NN NN hh NN h� NN NN NN N\rp �\tia � ° `° tia ti° �a a o a tia a a a a 4 4\ c aw a�� �*''� 'pi 9`��'t, ;s� g`� ary3�044 f`T<p��tig,��ti (—Total Volume Injected 9 Maximum Injection Pressure 1600 1400---.- 1200- 1000-- 800 600---- 400--- 200--- 0 IFY 111W ICZgig�6 lc� —,\e, gT, f 'p AT 4 P Dap LIN 0 Maximum Annular Pressure 160 140 120 100 IL 80 60 40 20 0 'r -----r- - - --r-� �- �tio `tio too ��yo `�o ��yo `ryo zo `�o ��o hyo �tio `tio \pyo ltio �`�'� A Days —NW SW —SE Limit u • 9 by RECEIVED Nov 01 2011 Alaska Oil & Gas Cans. Compassion BP Exploration (Alaska) Inc. 0 Ancho{up 800 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907)561-5111 CERTIFIED MAIL # 7011 0110 0000 4759 2781 October 28, 2011 UIC Manager, Ground Water Protection Unit Q� `C U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Re: Demonstration of Mechanical Integrity, Prudhoe Bay Pad 3, UIC Class I Permit AK -1 1004-B Dear UIC Manager: This letter is to submit the results of the required annual demonstration of mechanical integrity for the UIC Class I wells located at Pad 3 in the Prudhoe Bay Unit and operated by BP Exploration (Alaska), Inc (BPXA). The tests are required under Part ll, C.3 of EPA UIC Class I permit AK11004-B. The tests were conducted in compliance with the permit requirements and in accordance with approved procedures. EPA representative Thor Cutler witnessed the annulus pressure tests and the fluid movement logs. The annulus pressure tests, also known as Mechanical Integrity Tests (MITs) were performed in the three wells on September 21, 2011. Wells OWDW-NW and OWDW-SE passed the MITs. The fluid movement logging requirement was satisfied with borax -RST logs. These logs were run by service company Schlumberger in well OWDW-SE September 19 and in well OWDW-NW on September 20, 2011. There was no indication of fluid movement behind the casing above the approved injection interval in the NW and SE wells. Detailed information regarding the results of the MITs and the logs are contained in the attachments. They include descriptive and interpretive analyses of. the tests and logs and also copies of the borax -RST and temperature logs. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part ll, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564- 4692. Sincerely, Katharine Fontaine Logistics and Infrastructure Manager Attachments CC: with enclosures: Thor Cutler, EPA Region 10 Talib Syed, EPA consultant CC: w/o enclosures: Jim Regg, AOGCC Shawn Stokes, ADEC ZE Certified Mail # 70081830 0001 2706 5366 August 19, 2011 tion 1Alaskal Inc. 96612 900 E. Benson Boulevard AneftraF Anchorage, AK 99519-6612 USA UIC Manager, Ground Water Protection Unit,M;� .r I, ,�; y U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Re: Demonstration of Mechanical Integrity, Prudhoe Bay Pad 3, Well OWDW-SW, UIC Class I Permit AK -11004-8 Dear UIC Manager: This letter and the attached report is a follow-up to a letter submitted on November 2, 2010. This letter is to submit the results of additional tests performed in an attempt to satisfy part of the required annual demonstration of mechanical integrity for well OWDW-SW. This well is one of the three UIC Class 1 wells located at Pad 3 in the Prudhoe Bay Unit operated by BP Exploration (Alaska), Inc (BPXA). An annual demonstration of mechanical integrity including a standard annulus pressure test and a fluid movement test is required under Part 11, C.3.b.1 and b.2 of EPA UIC Class I permit AK11004-B. These tests were conducted in compliance with the permit requirements and in accordance with approved procedures. Annual surveillance was undertaken in well OWDW SW on September 24 and 25, 2010 with an EPA representative present. The fluid movement test requirement in the Pad 3 wells is normally satisfied with a borax -RST log along with shut-in temperature logs if necessary to provide additional information. These logs were run by service company Schlumberger in well OWDW-SW on September 24, 2010. An anomaly was noted above the packer on the borax -RST log Shut in temperature passes run after pumping ceased did not confirm the nomal . In addition, well OWDW-SW failed the annulus pressure test on September 25, 2010. There was no indication of a tubing leak prior to the annulus pressure test from routine tubing and annulus pressure moniroting. A leak detection log run on September 30, 2010 confirmed two leaks in the tubing string. A mechanical plug was installed in the tubing prior to the leak detect log, physically preventing any injection into the well. The well has remained shut-in with no disposal injection since September 23, 2010, before the logs were run. Additional logs were run to resolve the anomaly in OWDW-SW on July 16, 2011 with an EPA representative present. The logging required removal of the plug in the tubing. The logs included a repeat of the borax -RST and shut-in temperature logs and a series of waterflow log stops. The borax -RST and temperature logs did not show the anomaly see" September 24, 2010 borax -RST log, but the waterflow log indicated slow movement of fluids behind the casing in the same area as the anomaly. An area with no fluid movement was observed between the perforations and the anomaly. The tubing plug was re -installed in the well after these logs. Given the conflicting results, these logs failed to conclusively demonstrate that there is no vertical movement of fluids exterior to the casing. • • Detailed information regarding the results of the logs is contained in the attachments. They include a description of the test procedures used and a descriptive and interpretive analysis of test results. Also enclosed are copies of the borax -RST, temperature and waterflow logs. 1 certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, --- !Ktharine Fontaine Logsitics/Infrastructure Manager Attachments Cc: with attachments and log copies: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Cc: with attachments, w/o log copies: Jim Regg, AOGCC Marc Bentley, ADEC Mike Bill, BPXA MB 7-1 Alison Cooke, BPXA MB 4-3 T. Winkel/A. Reyes PRB 42 J. Murphy/M. Vazir PRB 24 Attachments: OWDW Surveillance Procedure OWDW Southwest Borax PNL Survey Results Enclosures: 2 copies of the following Schlumberger log: - OWDW-SW Schlumberger Reservoir Saturation / Borax I WFL Log, 16 -July -2011 • Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Surveillance Procedures Background EPA permit AK -1I004 -B, effective December 8, 2009, requires an annual fluid movement test, Part II C 3 b (2). Fluid movement tests were conducted in Pad 3 OWDW-SW and witnessed by an EPA representative on September 24, 2010. There was an anomaly noted above the packer in the OWDW-SW log. A report containing the results of that log and other tests was forwarded to EPA on November 2, 2010. Additional testing consisting of repeat Borax -RST and shut-in temperature logs and a Waterflow log was conducted July 16, 2011. The Borax-PNL technique involves comparing pulse neutron log (PNL) passes run before and after pumping a solution of borax dissolved in warm water as a tracer. Borax is composed of hydrates of sodium tetraborate. Boron has an inherently high neutron capture cross section. A PNL indicates a significantly higher Sigma value when boron is present, so an overlay of log passes quickly indicates those areas within and adjacent to the wellbore where boron accumulates due to injection of the tracer. This technique is commonly used for cement channel detection in development wells on the North Slope of Alaska. A PNL, Schlumberger's RST (Reservoir Saturation Tool) is utilized due to its availability at Prudhoe Bay and because it has been proven capable to detect the presence of boron laden fluids within and external to the wellbore. The tool has several other capabilities including measuring water movement adjacent to the casing called a Waterflow log. A Waterflow log was utilized in an attempt to understand the anomaly in the September 24, 2010 OWDW-SW log. Borax-PNL Survey - EPA permit AK- 1I004 -B requires tracer surveys to "... be run at injection pressures at least equal to the maximum continuous injection pressure observed in the well in the previous 6 months ...". The average and maximum injection pressures are reported quarterly on EPA Form 7520-8. - OWDW-SW was shut-in for the 6 months prior to logging. OWDW-SW average and maximum daily injection pressures prior to the September 24, 2010 log did not exceed 709 and 1062 psi respectively. Wellhead pressures were 1200 psi or above during the high rate pumping (5 barrels per minute) of borax solution. - The injection rate was reduced during individual log passes to minimize frictional drag on the logging tool due to high fluid velocities and small clearance between the tool (max diameter --l.72") and the 2-7/8" tubing ID (2.441" ) Shut-in Temperature Survey A baseline temperature survey was run prior to any pumping. The well has been shut in for over 9 months. A series of shut-in temperature passes were run to compare with the baseline temperature pass as the wellbore cools after injection ceases. Typically, a large channel outside the casing is indicated by a near constant temperature in the interval between the perforations and the top of the channel. The rate of wellbore cooling is also reduced in the channel interval. The first shut-in pass was run immediately after flushing borax from the well bore with hot water. Subsequent passes were run at one hour intervals. Page 1 of 2 • Prudhoe Bay Unit, EPA Permit: AK 1I004 -B OWDW Surveillance Procedures Waterflow Log In this mode, the RST tool is placed at a particular depth while pumping water. Thigh energy neutrons irradiate the formation and any fluids near the wellbore. The oxygen in water molecules is "activated" and subsequently undergo radioactive decay, essentially creating an in situ tracer. If water is moving in a channel outside the casing, that movement will be detected by the tool and an estimate of the velocity can be made. In some cases, fluid movement due to pumping heated fluids or even the heat generated by the tool itself can cause convective fluid movement in the tubing -casing annulus. Michael L. Bill., P.E. August 11, 2011 Page 2 of 2 0 • Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Southwest (Pad -3 SW) Background - On September 24, 2010, a borax -RST log was run as a fluid movement test in OWDW-SW. The log indicated an anomaly in the interval 1800-1812' MD, about 170 feet above the perforations and about 90 feet above the packer. The well has remained shut in since. - OWDW-SW failed an annulus pressure test on September 25, 2010. Subsequent testing and leak detection logging (September 30, 2010) confirmed holes in the tubing string at 850' and 1260' MD BGL (below ground level). Prior to running the leak detection log, a mechanical plug was installed in the tubing to facilitate the log and to prevent any disposal injection. - The plug was pulled from the tubing on July 15, 2011 in preparation for additional logging. - A follow-up survey was run on July 16, 2011 to confirm the well's mechanical integrity exterior to the casing and to provide additional information regarding the anomaly. Reference OWDW-SW Schlumberger Reservoir Saturation / Borax / WFL Log, 16 -July - 2010. The survey included repeat borax RST, shut-in temperature logs and a waterflow log. - Baseline temperature/pressure and RST sigma passes were run prior to pumping any fluids. After the baseline passes, about 100 barrels of warm water was pumped at 4-5 bpm and over 1000 psi well head pressure prior to the waterflow log stops and the sigma passes. - The maximum injection pressure during the 6 months prior to the September 24, 2010 log was 709 psi; the highest average pressure for any day in this period was 1062 psi. Wellhead pressures during the 7/16/11 logging while pumping at 5 bpm were 1100 psi or above. - A mechanical tubing plug was rerun in the tubing on July 20, 2011. Waterflow Log Results Waterflow stops were made in both "fast" and "slow" operating modes and both near and far detectors were used. Twelve stops were made from below the tubing tail to 215 feet above the top perforation, 35 feet above the 9/24/10 log anomaly. The deepest stop (1965') was made with the tool located below the tubing tail while pumping warm water at 5 bpm and 1100 psi wellhead pressure. Another stop was made at 1950', also with the tool below the tubing tail. The rest of the stops were made while the tool was within the tubing while pumping warm water. Injection rates were reduced while moving the tool to minimize the fluid frictional drag on the tool. A total of about 2000 barrels of warm water was pumped prior to and during the waterflow log. The waterflow tool indicated possible flow behind the casing at stops between 1965' and 1925'. Stops between 1890' to 1840' showed no indication of fluid movement. Stops at 1820', 1810, 1805' 1800', 1790', and 1765' showed low velocity movement in both the near and far detectors, from 2.8 to 4.7 ft per minute. These velocities are near the lower published operating range of the tool (3 to 210 ft/min). Based on a review of the waterflow log results with Schlumberger representatives, the following conclusions can be drawn: - The Far detector is considered the best tool for detecting low velocity flow. - The "slow" mode is best for detecting low velocity flow. - There is no indication of injected fluid movement near the well bore between 1890' and 1840', a distance of at least 50 feet. - The fluid movement observed may not be related to fluid injection during the logging, but it cannot be ruled out either. Given the relatively high rate of pumping, (5 bpm), it is unlikely that heat transfer from the hot RST tool to the annulus fluids could cause convective fluid movement in the annulus. Page 1 of 3 Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Southwest (Pad -3 SW) Borax-PNL Survey Results The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to above 1450' MD. In addition, sigma overlays of selected passes were prepared to compare the log response at various times during the survey. Each sigma overlay contains the following traces: formation gamma ray (API units), casing collar locator, formation sigma (capture units), borehole sigma (capture units). Sigma passes began after completion of the waterflow log. - "Baseline Overlay, 2000 Barrels KCL Away". The overlay compared the baseline pass from before any pumping to the pass run after the waterflow log. The difference in the two baseline passes gives an indication of the statistical variation in the tool response. There were no significant differences between the baseline passes. - "Borax Pass #1 Over Baseline, 130 barrels Borax Away". This overlay shows the change in tool response between the baseline pass and a pass run after pumping the first stage of borax solution at 5 bpm and 1200-1300 psi. During this pass borax solution was being pumped at 1 bpm to minimize tool drag. The shading on the overlay indicates areas of increased sigma. Below the tubing tail at 1907' MD BGL, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the tubing tail to about 1480', there is no statistically significant shift in wellbore sigma due to the very small volume of borax solution surrounding the tool while it is in the tubing (Tubing ID=2.441", RST Tool max OD= 1.72"). There is an indication of increased wellbore sigma above 1480', possibly related to the existing tubing leaks. There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. Typically, the increase in formation sigma due to the displacement of formation fluids adjacent to the wellbore with borax solution is 2-1/2 to 6 chart divisions or 5 to 12 capture units. - "Borax Pass #2 Over Baseline 160 BBLS Borax Away". An additional 30 barrels of boron laden fluid was pumped at 5 bpm and 1200 psi prior to running this pass. There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. - "KCL Flush Over Baseline 45 Barrels KCL Flush". This overlay shows the tool response after flushing the wellbore with warm water at low pump rates. Again, there is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. The wellbore sigma below the tugging tail has returned to baseline levels. This overlay also shows the statistical variation in the tool response and again insures the tool is functioning properly. - There was no repeat of the anomaly seen in the 9/24/10 borax -RST log and no indication of the flow of boron laden fluid above the perforations. Baseline and Shut -In Temperature Passes - The baseline temperature pass was run to provide a basis of comparison for subsequent passes and to compare with the baseline pass run for the 9/24/10 log. The well had been shut in for over 9 months when the 07/16/11 log was run and for about 1 day before the 9/24/10 baseline temperature pass. - The 07/16/11 baseline temperature log is similar in character and absolute temperatures to the baseline temperature surveys run in the past and similar to the 9/24/10 baseline log. These logs show significant permafrost warming due to vertical and radial heat transfer from injection operations from the perforations up to about 1650' MD. Page 2 of 3 0 E Prudhoe Bay Unit, EPA Permit: AK -11004-B OWDW Southwest (Pad -3 SW) - Five Shut -In Temperature passes were run after pumping ceased to provide additional information. The passes were run immediately after pumping ceased and subsequently after 1 hour intervals. - As with the temperature passes run as part of the 09/24/10 log, an overlay of the 07/16/11 temperature passes gave no indication of fluid movement upward from the perforations. The character of each pass was similar and the rate of cooling back towards the baseline was consistent between passes. Overall Conclusions The sigma anomaly noted between 1800' and 1812' in the 9/24/10 borax -RST log was not present in the repeat borax -RST log run on 07/16/11. The Waterflow log stops showed low fluid velocity from 1820' to 1765'MD BGL, however there was no indication of fluid movement between 1890 and 1840'. The top perforation is at 1980'. The baseline and shut-in temperature passes do not indicate a channel behind the casing. The conflicting information from the logs does not allow conclusive confirmation of no fluid movement upward from the perforations behind the casing. The following are additional conclusions from the 07/16/11 logging. 1. There is no indication of channeling behind casing uphole from the perforated interval on the Borax -RST sigma passes. 2. There was no indication of channeling behind casing uphole in a 50' interval between 1890' and 1840' from the Waterflow log stops. 3. Waterflow log stops indicate low velocity movement between 1820 and 1765' MD. The velocity indicated is near the published lower threshold of the tool. 4. Post pumping shut-in temperature passes showed no evidence of channeling near the wellbore and did not confirm the waterflow movement indications. 5. In general, these results (other than the anomalous intervals) are consistent with prior surveillance indicating that injection probably takes place through a horizontal fracture within or near the perforations. There is a large area of reservoir permeability damage near the wellbore from past injection. (Reference: Section 6, UIC Class I Permit Application for the Pad 3 Injection Facility, submitted February, 18, 1999). The results of both the 9/24/10 Borax RST / Temperature log and the 07/16/11 Borax -RST, Waterflow and Temperature logs, do not provide conclusive proof that there is no upward movement of injected fluid behind the casing. Michael L. Bill, P.E. August 11, 2011 Page 3 of 3 by►;�; Certified Mail # 7011 0110 0000 4759 1739 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 July 28, 2011 (907) 561-5111 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 RE: Second Quarter 2011 — Pad 3 Injection Well Monitoring UIC Class I Permit AK — 11004-B Dear UIC Manager: AIN, J C \o W This report is being submitted to fulfill the second quarter 2011 (April - June) reporting obligations for the above referenced permit. Enclosed are three forms [EPA 7520-8 (2- 84)] containing the information required by Part II, Section E of the permit. Also attached is a listing of the types and volumes of materials injected during the reporting period, a CD of the raw data, and graphs showing injection pressure, annular pressure, and injection volume for the wells. A description of the wastes managed at Pad 3 has been previously submitted to the EPA in the Waste Analysis Plan (WAP). The enclosed graphs and the raw data being submitted electronically on CD are a requirement under the Pad 3 UIC Permit (AK -1 1004-13). There are no permitted limits for the pH and temperature of the injected fluids. They are included in the reports as a physical description of the injected fluids (see Part II, Section E (1)(b) of the permit). The pH values define the non -hazardous range allowed for non- exempt fluids injected and the temperature values define the range historically encountered. A calibration of pressure instrumentation on April 4th, 2011 resulted in high pressure readings above permit limits for NW, SW and SE wells. During this time the pumps were shut down and no injection was taking place. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. 0 • UIC Manager July 28, 2011 Page 2 If you need any clarification or additional information concerning these reports, please contact Alison Cooke, at (907) 564-4838 or Alison.Cooke@bp.com. Sincer ly, Kathy Fontain Logistics/Infrastructure Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2011 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum Aril May June 0 0 0 0 0 0 2,000 0 0 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 199 0 0 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 0 0 0 0 0 0 Temperature (F) 1. Minimum 2. Average 3. Maximum N/A N/A N/A N/A N/A N/A N/A N/A N/A pH 1. Minimum 2. Average 3. Maximum N/A N/A N/A N/A N/A N/A N/A N/A N/A Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 0 0 0 0 0 0 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SW Well ADEC 9821 - D6001 EPA Well Permit No. AK - 11004A Name and Official Title ignature Katharine Fontaine Infrastructure/Logistics ,Manager Date Signed EPA Form 7520-8 (2-84) 1 The values provided define the non - hazardous range and are not measured values. See Waste Analysis Plan. Values in parentheses ( ) are actual values for permit compliance. • UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2011 Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum MONTH MONTH MONTH Aril May June 0 0 149 187 405 607 2,001 1,148 1,047 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 0 0 18 44 66 135 136 100 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 15 17 18 19 21 200 33 32 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 153,533 866,111 1,457,509 2,731,174 3,597,285 5,054,794 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 5,118 27,939 48,584 55,860 89,754 90,527 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519 - 6612 Permit Number NW Well ADEC 9821 - D13001 EPA Well Permit No. AK - 11004A Name and Official Title Katharine Fontaine Infrastructure/Logistics Manager Signature Date Signed EPA Form 7520-5 (2-54) *The values provided define the non -hazardous range and are not measured values. See Waste Analysis Plan. Values in parentheses ( ) are actual values for permit compliance 0 0 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2011 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum Aril May June 0 268 53 600 744 732 2,047 1,050 1,243 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 101 99 87 113 116 105 139 142 140 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 14 14 18 17 16 202 25 22 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 553,501 3,238,171 2,756,998 3,207,581 6,445,752 9,202,750 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 21,919 104,457 91,900 99,658 187,517 158,760 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SE Well ADEC 9821-DB001 EPA Well Permit No. AK -11004A Name and Official Title Katharine Fontaine Infrastructure/Logistics Manager Si ature Date Signed EPA Form 7520-8 (2-84) The values provided define the non -hazardous range and are not measured values . See Waste Analysis plan . The values in parenthesis ( ) are actual values for compliance purposes . 0 Pati 3 - Injection Composition Summary North Slope Technical Services 041011201' to 0613012011 Equipment services Group %4,4,14 By Component Component Barrels Acid 3.50 aqua mag solution 3.00 auto processing fluids 12.00 Soifer Slowdown 245.00 cellar box fluids 479.00 Cement rinsate 247.50 Cement/Contaminate 5,274.25 Chemclear 1.00 class 1 rinsate 10,431.00 class 1 sump fluids 551.91 class 2 rinsate 12, 737.00 Condensate 36.00 Crude Oil 6.574.85 Cuttings 49.31 Diesel 671.68 Diesel/Water Gel 1,054.53 Domestic Water 2.00 Drilling Mud 3,741.05 Drum rinsate 25.00 Expired Lab Standards/Rinse 1.00 Fresh Water 66,455.27 geo viz 7.50 Glycol 133.36 Gravel/Sand 0.99 Hydrotest Fluid (water) 300.00 lab fluids 0.05 Line pigging solids 0.36 Lube oil 100.00 Methanol 505.28 non haz soap 6.65 pigging fluids 37.00 GarneAe ." aao lOJil-MaNfkgEAa6-Rh Zl Printed on Saturday, July 09, 2011 Page 1 of 3 0 0 Pad 3 - Injection tv Composition Summary 11�14'0� North Slope Technical Services 0 z 0410112011 to 0613012011 Equipment Services Group 11144 � By Component Component Barrels Produced Water 12,270.10 Reserve/Flare/Relief Pit Water 2,590.00 Rinsate 2,982.00 Safe Break L (from downhole) 25.00 safe soiv soap 2.90 Safe Surf 0 surfactant 58.00 Scale/Corrosion Inhibitor 5.40 sealtite 1.10 Seawater/Brine/KCI 35,770.62 snow melt 26,815.20 SNOW MELT WELL CELLAR 20.89 Snowmeit 22,578.00 snowmelt/ponded water 97.00 Soap 0.30 Soda ash 431.50 soda ash solution 322.50 Sodium thiosulfate standard solution 0.50 Source Water 290.00 SPILL CLEANUP MATERIAL 2,949.00 Spill Cleanup Waste 940.00 storm water 442.60 stormwater 426.80 sulfide 2 reagent 1.00 Sump fluids 5,376.90 teg,water,sait&silver nitrate 0.02 unknown liquids 0.50 used calibration solution 1.00 various caustics 0.02 vessel solids 35.00 washing machine water 42.00 well cellar fluids 15,938.00 0HHaMuAhg Attrots T000-I[Mubs6E ..�•Rs✓T% Printed on Saturday, July 09, 2011 Page 2 of 3 Pad 3 - Injection Composition Summary 40 North Slope Technical Services 0410112011 to 0613012011 Equipment Services Group t-,4� By Component Component Barrels WR6 Soap 0.50 x-ray fluids Total Volume: a.m.r+a gems A- 2W. Mu WEm -R-a9 Printed on Saturday, July 09, 2011 1.32 240,102.72 Page 3 of 3 50000 N ca 30000 m 20000 10000 0 Total Well Volumes p\`t' Days Total Volume Injected 0 is 2500 2000 1500 N CL 1000 W 0 p\ p\ p\ p\ p\ pP p\r' p\`L pP p\`L Days Maximum Injection Pressure NW SW SE - Limit n �J 250 200 150 �N CL 100 0 Days Maximum Annular Pressure NW SW SE —Limit C� 120000 100000 T �a 60000 m 40000 20000 Total Well Volumes Days Total Volume Injected 9 0 1600 1400 1200 1000 CL 800 e 400 200 0 h h h 4 h h h h h h 41 Days Maximum Injection Pressure -----NW - SW SE — Limit 0 0 Maximum Annular Pressure 120000 100000 T ca 60000 m 40000 20000 0 Total Well Volumes Co bl bl bN 4 �o� J\ Days Total Volume Injected 0 0 1600 1400 1200 1000 Maximum Injection Pressure WE 400 200 0 �o R (o Go (b R) (off Days NW -- S W SE Limit 0 0 160 140 120 100 a 80 .c 40 20 0 �0 0 ro ro ro �o� �o� rod rodA r\ �o� Days Maximum Annular Pressure NW SW SE Limit 0 J Q. r: to • Schlumburber Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503.2838 ATTN: Stephanie Pacillo Well Job # RECEIVED JUL ) 5 2011 Abft 01 & Gn COn8- Ciwm*" Anrcil0iW Log Description No. 5769 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Shartzer 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H -17A BLPO-00119 PPROF W GHOST 10 -Jul -11 1 1 14-04A AV1P-00093 LEAK DETECTION LOG 9 -Jul -11 1 1 E -01A BLPO-00121 PPROF W GHOST 12 -Jul -11 1 1 MPB-50 BCRJ-00096 RST WFL LOG 16 -Jul -11 1 1 H -14B BD88-00113 PPROF WI DEFT & GHOST 2 -Jun -11 1 1 $ OWDW-SW AV1P-00091 RST WFL LOG 16 -Jul -11 1 -1 06-02A BL65-00027 LDWG EDIT OF MCNL 4 -May -11 1 1 15-02B BJOH-00016 LDWG EDIT OF RST 1 -Apr -1 1 1 1 P2-41 BJOH-00020 LDWG EDIT OF RST 11 -Apr -1 1 1 1 W-223 BC°RJ-00086 I LDWG EDIT OF USIT 18 -May -11 NIA 1 W-202 BMSA -00005 LDWG EDIT OF USIT 30 -Jan -11 NIA 1 06-08A BCRD-00089 LDWG EDIT OF RST 6 -Mar -11 1 1 PLEA6t A(.;KNUVVLtUUt KtC:tIF' I BY 6IUNINU AND Kt I UKNINU UNt UUrY CAv-rl 1U. BP Exploiatir�n (Alaska) Inc. Petrote(:hnical Data Center L R2 'I 900 E"_- Nensnn Blvd 0 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 bp Af' r, Certified Mail # 7011 0110 0000 47591470 April 29, 2011 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 10® -ads RE: First Quarter 2011 — Pad 3 Injection Well Monitoring Report UIC Class I Permit AK —11004-B C, ®V.�1J C E' ,Z;_, f_, V MAS 6= Dear UIC Manager: This report is being submitted to fulfill the first quarter 2011 (January - March) reporting obligations for the above referenced permit. Enclosed are three forms [EPA 7520-8 (2- 84)] containing the information required by Part II, Section E of the permit. Also attached is a listing of the types and volumes of materials injected during the reporting period, a CD of the raw data, and graphs showing injection pressure, annular pressure, and injection volume for the wells. A description of the wastes managed at Pad 3 has been previously submitted to the EPA in the Waste Analysis Plan (WAP). The enclosed graphs and the raw data being submitted electronically on CD are a requirement under the Pad 3 UIC Permit (AK -1 1004-13). There are no permitted limits for the pH and temperature of the injected fluids. They are included in the reports as a physical description of the injected fluids (see Part II, Section E (1)(b) of the permit). The pH values define the non -hazardous range allowed for non- exempt fluids injected and the temperature values define the range historically encountered. There were no limit exceedances during the quarter. I certify under penalty of law that 1 have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. UIC Manager April 29, 2011 Page 2 If you need any clarification or additional information concerning these reports, please contact Alison Cooke, at (907) 564-4838 or Alison.Cooke@bp.com. Sincerely, IG I Gar l Kathy Fontaine Logistics/infrastructure Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC y I la - UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2011 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum January February March 0 0 0 0 0 0 0 0 0 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 0 0 0 0 0 0 Temperature (F) 1. Minimum 2. Average 3. Maximum N/A N/A N/A N/A N/A N/A N/A N/A N/A pH 1. Minimum 2. Average 3. Maximum. N/A N/A N/A N/A N/A N/A N/A N/A N/A Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 0 0 0 0 0 0 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SW Well ADEC 9821 - DB001 EPA Well Permit No. AK - 11004A Name and Official Title Katharine Fontaine Logistics/Infrastructurew_ Manager Signature N Date Signed EPA Form 7520-8 (2-84) ' The values provided define the non - hazardous range and are not measured values. See Waste Analysis Plan. Values in parentheses ( ) are actual values for permit compliance. Pad 3 - Injection ij Composition Summary North Slope Technical Services 01101/2011 to 03/31/2011 Equipment services Group By Component Component Barrels Acid 42.50 Ammonium chloride 25.00 Arctic Pac 142.50 arctic pack 30.05 Boiler Blowdown 224.60 cellar box fluids 29.00 Cement/Contaminate 2,163.67 Chemicals 1.20 chlor -rid 0,03 citrus based cleaner 0.00 class 1 floor sump 83.00 class 1 rinsate 9;116.00 class 1 sump fluids 1,047.80 Gass 1 well cellar fluid 2.00 class 2 rinsate 8,558.00 class 2 solids 4.90 Class 2 Sump Fluids 40.00 classl rinsate 240A0 Crude Oil 2,892.82 Cuttings 0.35 Diesel 751.57 Diesel/Water Gel 421.10 Domestic Water 63.70 Drilling Mud 2,397.23 Drum rinsate 60.00 Emulsion breaker 0.50 Frac Sand 2.50 freeze protect / down hole 10.00 Fresh Water 38,760.27 Glycol 76.51 Gravel/Sand 1.72 G~,dux.vM-2M.MU *S E .9. R� Z2 Printed on Sunday, April 10, 2011 Page 1 of 3 9 • North Slope Technical Services 01!01/2011 to 03/31/2011 Equipment Services Group By Component Component Barrels Hydrotest Fluid (water) 835.00 lathe coolant 1.00 Line pigging solids 355.00 Methanol 626.46 Mineral oil 27.50 nalco 2828 plus 1.00 off spec product 1.00 parts washer fluid 52.00 Photo processor fluids 12.00 pigging fluids 115.00 Produced Water 8,010.20 production facility fluids 0,29 reserve pit fluids 675.00 reserve pit water 675.00 Reserve/Flare/Relief Pit Water 3,375.00 Rinsate 950.00 Scale/Corrosion Inhibitor 2,70 Seawater/Brine/KCI 31,690.44 snow melt 590.00 Snowmelt 801.50 Soap 0.95 Soda ash 672.55 soda ash solution 100.00 SPILL CLEANUP MATERIAL 151.00 Spill Cleanup Waste 90.00 Sump fluids 5,666.88 sump fluids / snowmelt 13.00 turbine wash 1.30 washing machine water 22,50 water based parts cleaner 3.00 well cellar fluids 292,02 GeMrerW„wy Amsf ?". MmNVFE rn E. R- 2 SC Printed on Sunday, April 10, 2011 Page 2 of 3 Pad 3 - Injection �3.. Composition Summary North Slope Technical Services 0110112011 to 0313112011 Equipment Services Group By Component Component Barrels WR6 Soap 1.99 Total Volume: G�n�raroC uavp Acnes .w-,.uhUFE-- F®v? S Printed on Sunday, April 10, 2011 123,000.81 Page 3 of 3 • KE Certified Mail # 7010 0290 0000 8492 5548 January 20, 2011 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 BP Exploration (Alaska) Inc 900 East Benson Boulevard PO Box 196612 Anchorage, AK 99519-6612 (907) 564-5111 RE: Fourth Quarter 2010 — Pad 3 Injection Well Monitoring Repo r g, UIC Class I Permit AK —11004-B'� '_OCtS�Cr"Ii Dear UIC Manager: This report is being submitted to fulfill the fourth quarter 2010 (October - December) reporting obligations for the above referenced permit. Enclosed are three forms [EPA 7520-8 (2-84)] containing the information required by Part II, Section E of the permit. Also attached is a listing of the types and volumes of materials injected during the reporting period, a CD of the raw data, and graphs showing injection pressure, annular pressure, and injection volume for the wells. A description of the wastes managed at Pad 3 has been previously submitted to the EPA in the Waste Analysis Plan (WAP). The enclosed graphs and the raw data being submitted electronically on CD are a requirement under the Pad 3 UIC Permit (AK -1 1004-13). There are no permitted limits for the pH and temperature of the injected fluids. They are included in the reports as a physical description of the injected fluids (see Part II, Section E (1)(b) of the permit). The pH values define the non -hazardous range allowed for non- exempt fluids injected and the temperature values define the range historically encountered. There were no limit exceedances during the quarter. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. UiC Manager January 20, 2011 Page 2 If you need any clarification or additional information concerning these reports, please contact Alison Cooke, at (907) 564-4838 or Alison.Cooke*bp.com. Sincerely, *4410 Kathy Fontaine LogisticsAnfrastructure Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC • • UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2010 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum October November December 8 0 0 13 9 3 27 12 8 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 16 0 1 25 11 4 37 16 8 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 0 0 0 15,155,104 15,155,104 15,155,104 Temperature (F) 1. Minimum 2. Average 3. Maximum N/A N/A N/A N/A N/A N/A N/A N/A N/A PH 1. Minimum 2. Average 3. Maximum N/A NIA N/A N/A N/A N/A N/A N/A N/A Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 0 0 0 0 0 0 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SW Well ADEC 9821 - DB001 EPA Well Permit No. AK -11004A Name and Official Title Katherine Fontaine Logistics/Infrastructure Manager Si ature '4 Date Signed / EPA Form 7520-8 (2-84) r • The values provided define the non -hazardous range and are not measured values. See Waste Analysis Plan. Values in parentheses ( ) are actual values for permit compliance . 0 0 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2010 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum October November December 178 0 127 520 596 545 964 998 992 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 76 75 91 106 100 107 137 138 141 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 39 0 21 48 34 26 68 48 40 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 997,345 934,349 1,002,729 997,345 1,931,693 2,934,422 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 32,172 31,145 32,346 108,406 1 70,220 110,195 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SE Well ADEC 9821-DB001 EPA Well Permit No. AK -11004A Name and Official Title Katherine Fontaine Logistics/Infrastructure Mana er S gnature Date Signed Crw rorm /azu-a jz-a4) ' "The values provided define the non -hazardous range and are not measured values . See Waste Analysis plan . The values in parenthesis ( ) are actual values for compliance purposes . 1 cep- a3ci 0 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2010 Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum MONTH MONTH MONTH October November December 312 0 282 467 471 456 758 740 810 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 98 80 0 106 102 103 138 140 142 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 53 0 51 62 61 60 86 85 90 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 1,001,204 947,780 927,457 16,725,218 17,672,999 18,600,455 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 32,297 31,592 29,918 107,726 69,321 107,852 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519 - 6612 Permit Number NW Well ADEC 9821 - DB001 EPA Well Permit No. AK - 11004A Name and Official Title Katherine Fontaine Logistics/Infrastructure Manager Si nature Date Signed EPA Form 7520-8 (2-84) 'The values provided define the non - hazardous range and are not measured values. See Waste Analysis Plan, Values in parentheses ( ) are actual values for permit compliance Pad 3 - Injection by Composition Summary Natth Slope Technical Services 0 10/01/2010 to 1213112010 Equipment Services Group By Component Component Barrels Acid 3.70 Arctic Pao 938.00 Boiler Blowdown 696.65 brine 43.50 Cement/Contaminate 6,013.13 class 1 floor sump 140.00 class 1 rinsate 15,855.00 class 1 sump fluids 1,038.90 class 2 rinsate 7,032.41 Class 2 Sump Fluids 76.00 Crude Oil 3,055.52 Cuttings 79.25 Diesel 1,078.05 Diesel/Water Gel 965.80 Domestic Water 260.00 Drilling Mud 3,584.65 Drum rinsate 27.00 DT -3000 5.50 EC9360A Dispersant 0.16 ec96609 surfactant 0.53 exempt spill cleanup 80.00 Fresh Water 37,181.46 Glycol 288.77 Gravel/Sand 15.13 hot water 34.65 Hydrotest Fluid (water) 360.00 lab fluids 1.00 lathe coolant 3.00 Une pigging solids 50.00 Methanol 874.77 non haz soap 0.95 o,n.,w�..M w.w,.w, rr�.nu„� • w.. e w Printed on Wednesday, January 05, 2011 Page 1 of 2 Pad 3 - Injection bp Composition Summary North Slope Technical Services 1010112010 to 1213112010 Eclulpment services GrouP By Component Component Barrels NRDC 0.32 off spec product 1.130 parts washer fluid 10.D0 Photo processor fluids 12.03 pigging fluids 70.00 Produced Water 6,571.79 production facility fluids 100.00 Rinsate 594.00 rinse fluids 50.00 Scale/Corrosion Inhibitor 0.35 schmoo b gone 24.50 SeawatedBrinell(Cl 36,581.70 snow melt 1,062.00 Snowmeit 580.00 snowmelt/rainwater 2.00 Soap 1.80 Soda ash 391.85 soda ash solution 4.85 Spill Cleanup Waste 279.00 Sump fluids 6,043.25 Sump solids 3M Thennatek 3.00 Turbine washwater 6.90 Used Oil 0.03 well cellar fluids 95.00 Total Volume: 132,271.86 Printed on Wednesday, January 05, 2011 Page 2 of 2 5000( 4500( 4000( 3500( 3000( 25001 m 20001 15001 10001 M 0 Rp Rp hp h4 R4 hd RA RO h0 r�0 '�� r�� rid RCO RO h4 ha`�� RO�y� N� � RO`�\ O`h~� O`R�� 4O�R,�� ©`Rg� O`r1h� OM�ry�� o,�y� O`'0 4\ev Q`�►�� R h R h R �. R R R h Days Total Well Volumes —Total Volume Injected C� U Maximum Annular Pressure 160 140 120 100 80 60 40 20 0 NZ, NSzo pp Cop \b 'z'� Days NW �—Sw SE i —Limit 0 0 Maximum Injection Pressure 1600 1400 1200 1000 - - - _ --- _ --- __ IL 800 __ .__ ----- 600 _ 400 _ _-.________ ____.-____- 200 0 "ooh � Ro\� 11 01� OKI3 11p\ry�, Days NW —SW SE — Limit i Total Well Volumes —Total Volume Injected • Maximum Annular Pressure 160 140 120 100 80 IL 60 40 20 0 N(Z� Nei NN Days NW :—Sw I—SE ,—Limit 0 1600 1400 1200 1000 a 800 600 400 200 0 NN NN h "N NN NJ\ Days Maximum Injection Pressure —NW SW SE — Limit CJ r� L 50000 4500C 4000C 3500C 3000C 2500( m 2000( 1500( 1000( 500( 0 ,gyp �p ,gyp �p ,gyp ,gyp 1+p ,gyp ,gyp �O 41O �,O �p �.<p t" < �. Days Total Well Volumes --Total Volume Injected f n U Maximum Annular Pressure 160 140 120 100 M gp a -- 60 40 20 0 NO NO�O O „�O N11.)NIZ, ,�O NltO �O ,`O ,�O ,�O ,�O ,�O Nlc , Days !--NW SW SE Limit Maximum Injection Pressure 1600 1400 1200 1000 �► 800 a 600 _. _- -_------- 200 ---200 0 \gyp \N0 \gyp \ gyp `gyp p `gyp `gyp `,gyp �,�0 p �,`p `�O ��O \ti4 Np ►�`L �ti� �`Ly ��1 ��p ►� � hip ti�%,�`L�`1�~p �` �� �`i%�p ►�`1�4f'l NIP 41 Days —NW i SW SE — Limit 0 0 # 0 arc rja,/y Dafa-�fQ�p .41 ia} 1 f G sUons ? 1-800-425-0049 Alaska Data B Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO. 5648 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Shartzer 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD PLEASE ACKNOWLEDGE RECEIPT BY 51GNING AND Kt I UKNING UNt CUP7 CAt M IV: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Pelrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 AdWtFX DEC. (16 2011 M 11/24/10 0 s o�-2.LAUi���� .or_mc��s�� �m� ®mss oRF— L PLEASE ACKNOWLEDGE RECEIPT BY 51GNING AND Kt I UKNING UNt CUP7 CAt M IV: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Pelrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 AdWtFX DEC. (16 2011 M 11/24/10 0 s s +� CERTIFIED MAIL #f 7010 0290 0000 8492 5210 November 2, 2010 amu) NGS! 0 8 MO • 64111-14 BP Exploration (Alaska) Inc. P. 0. Box 196612 900 E. Benson Boulevard Anchorage, Ah 99519-6612 Direct 907 561 5111 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) NOV 0 5 2010 1200 Sixth Avenue, Suite 900 AWAI" it Ga uOvy Seattle WA 981016�� RE: Demonstration of Mechanical Integrity, Prudhoe Bay Pad 3, UIC Class I Permit AK -1 1004-B o' JJ Dear UIC Manager: This letter is to submit the results of the required annual demonstration of mechanical integrity for the three UIC Class I wells located at Pad 3 in the Prudhoe Bay Unit and operated by BP Exploration (Alaska), Inc (BPXA). The tests are required under Part II, C.3 of EPA UIC Class I permit AK11004-B. The tests were conducted in compliance with the permit requirements and in accordance with approved procedures. EPA representative Thor Cutler witnessed the annulus pressure tests and the fluid movement logs. The annulus pressure tests, also known as Mechanical Integrity Tests (MITs) were performed in the three wells on September 25, 2010. Wells OWDW-NW and OWDW-SE passed the MITs, but well OWDW-SW failed the test. The fluid movement logging requirement was satisfied with borax -RST logs along with shut-in temperature logs if necessary to provide additional information. These logs were run by service company Schlumberger in well OWDW-SE September 23 and in wells OWDW- NW and SW on September 24, 2010. There was no indication of fluid movement behind the casing above the approved injection interval in the NW and SE wells, but an anomaly appeared in the SW well log. Shut in temperature passes were run after pumping ceased to provide additional information. The temperature passes did not confirm the anomaly. The SW well has remained shut in. A leak detection loo run in OWDW-SW on 9/30/10 confirmed two leaks in the tubing string. Detailed information regarding the results of the MITs and the logs are contained in the attachments. They include descriptive and interpretive analyses of the tests and logs and also copies of the borax -RST and temperature logs. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. UIC Manager • November 2, 2010 Page 2 BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part ll, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. Sincerely, 'ZI_ Kathy Fontaine Logistics/Infrastructure Manager Attachments Cc: w/o enclosures: Thor Cutler, EPA Region 10 Talib Syed, EPA consultant Jim Regg, AOGCC Shawn Stokes, ADEC Mechanical Integrity Test Results Pad 3 OWDW Injection Wells Prudhoe Bay Unit Annulus pressure tests on the Class I Oily Waste Disposal Wells at Pad 3 were performed on September 25, 2010. The tests were performed in accordance with the stipulations of the permit. In each well, the nitrogen cushion was bled off and displaced with diesel. The annulus was then pressured to above 1500 psi and observed for 30 minutes. The results of the tests were as follows: In the NW and SE wells, the pressure decline was less than 10 percent during the test period, with less than 1/3 of the total decline in the second half of the 30 minute period. This shows a stabilizing tendency as specified in EPA Permit AK -11004-A, Part II, C 3 b (1). Annulus pressures were observed on a test gauge. During the test period, the tubing pressure was essentially constant in the NW and SE wells. The pressure decline observed in these wells may be the result of shrinkage due to cooling of the well fluids during the test. The SW well failed its test with a significant loss in annulus pressure indicating the development of a tubing, casing or packer leak. Subsequent logging to determine the leak point verified two tubing leaks in the SW well. There had been no indication of a tubing leak from monitoring the annulus during normal injection operations. The well remains shut in and repair options are under evaluation. The testing was witnessed by EPA representative Thor Cutler. I conclude from the successful MIT's that the casing, tubing and packer in the NW and SE wells are in sound mechanical condition. This is consistent with the absence of any indication of tubing or packer leakage during normal injection operations when there is a large pressure differential (>500 psi) between the tubing and the annulus in each of the wells. Michael L. Bill October 15, 2010 Tubing Pressure Annulus Pressure psi 1st Half 2nd Half Test Pad 3 Well Start / End Start 15 Min 30 Min Decline Decline Result Northwest 426/429 1515 1409 1385 106 24 Passed Southwest 525/- 1500 <1300 >200 FAILED Southeast 309/307 1535 1444 1420 91 24 Passed In the NW and SE wells, the pressure decline was less than 10 percent during the test period, with less than 1/3 of the total decline in the second half of the 30 minute period. This shows a stabilizing tendency as specified in EPA Permit AK -11004-A, Part II, C 3 b (1). Annulus pressures were observed on a test gauge. During the test period, the tubing pressure was essentially constant in the NW and SE wells. The pressure decline observed in these wells may be the result of shrinkage due to cooling of the well fluids during the test. The SW well failed its test with a significant loss in annulus pressure indicating the development of a tubing, casing or packer leak. Subsequent logging to determine the leak point verified two tubing leaks in the SW well. There had been no indication of a tubing leak from monitoring the annulus during normal injection operations. The well remains shut in and repair options are under evaluation. The testing was witnessed by EPA representative Thor Cutler. I conclude from the successful MIT's that the casing, tubing and packer in the NW and SE wells are in sound mechanical condition. This is consistent with the absence of any indication of tubing or packer leakage during normal injection operations when there is a large pressure differential (>500 psi) between the tubing and the annulus in each of the wells. Michael L. Bill October 15, 2010 a • Unites! States Environmental Protection Agency Region 10 �moo a 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-NW AK -11004-A 1002400 Injector MIT Type I Test Type Test Date Class [ T X [A I Std. Annular Pressure Test (SAPT) 1 9/25/2010 Req'd Test Presssure (psi) Fluid Type(s) used to test Packer Depth (ft, TVD) Test Interval / Comments 1,500 Diesel 1,900' One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or St during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T E S T START TIME: 14:45 am/pm PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT P/F P TUBING 426 427 432 429 INNER ANNULUS 17 1515 1409 1385 OUTER ANNULUS 1 COMMENTS: 2 bbls diesel to load IA & 1.5 bbls to pressure IA T E S START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ TUBING T 2 INNER ANNULUS FAIL OUTER ANNULUS COMMENTS: T E S T 3 START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MtN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS OUTER ANNULUS COMMENTS: MISC COMMENTS: Last MIT SAPT September 2009 Originally drilled in the 1970s to test the thaw charactenstics of permatrost. 2006 MIT SAPT was to 1610, lost 20 psi in 30 minutes. NOTE: Pressure must show stabilizing tendency: l) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Stan MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). 0 0 -- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler/Tim Mayer Declined Jeff Jones / John Crisp Jerry Murphy • United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-SW AK -11004-A 1002380 Injector MIT Type I Test Type Test Date Class I T X IA I Std, Annular Pressure Test (SAPT) 9/25/2010 Req'd Test Fluid Type(s) used to testTVD) Packer Depth (ft, Test Interval /Comments Presssure (psi) INNER ANNULUS 25 1500 OUTER ANNULUS 1,500 Diesel 1,902' 1 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T E S T 1 START TIME: 6:10 PM RECORDED PRESSURES (PSI) PRE MIT INITIAL 1 15 MIN 30 MIN 45 MIN 60 MIN RESULT P/F FAIL TUBING 525 525 INNER ANNULUS 25 1500 OUTER ANNULUS COMMENTS: IA pressure fell off -200 psi per minute during multiple tests Load IA w/ 2.1 bbls diesel; 0.3 bbls to pressure up T E S T 2 START TIME: 7: t2 PM PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT FAIL TUBING 525 525 INNER ANNULUS 0 1550 OUTER ANNULUS COMMENTS: IA pressure lost -200 psi in less than one minute T E S T START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN]_60 MIN RESULT TUBING INNER ANNULUS OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: Last test MITIA -10/8/08 (witness T.S ed/T.Cutler), Borax-PNUtemp survey - 10/5/08. Originally drilled in the 1970s to test the thaw characteristics of permafrost. Last ran MITIA to 1600 psig on 10/8/08. toss was 80 psi after 15 min and 100 psi after 30 min (less than 10 % allowable) NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). 0 o-- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler/Tim Mayer Declined Jeff Jones /John Crisp Jerry Murphy United States Environmental Protection Agency Region 10 $., 1200 Sixth Avenue, Suite 900 St �Re�4 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility I Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-SE AK -11004-A 1002390 Injector MIT Type Test Type Test Date Class I T X IA I Std. Annular Pressure Test (SAPT) 9/25/2010 Req'd Test Presssure (psi) Fluid Type(s) used to test Packer Depth (It, TVD) Test Interval / Comments 1,500 Diesel 1,885' 1 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T E START TIME: 12:15 PM PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PIF S T 1 TUBING 309 313 307 307 P INNER ANNULUS 34 1535 1444 1420 OUTER ANNULUS COMMENTS: 2.5 bbls diesel to load IA 2 bbls to pressure to Tubing pressure obtained from facility Rosemont gauge T E START TIME: PRE MIT I RECORDED PRESSURES (PSI) INITIAL 1 15 MIN 30 MIN 45 MIN 60 MIN RESULT S TUBING PASS/ T 2 INNER ANNULUS FAIL OUTER ANNULUS COMMENTS: T E S T START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS OUTER ANNULUS 3 COMMENTS: RISC COMMENTS: last SAPT Sept 2009 Originally drilled in the 1970s to lest the thaw characteristics of permatrost. MITIA on 2006 at 1600 lost 10 psi over 30 minutes NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if. 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, it necessary, to eliminate thermal effects (on-site decision per Inspector). — E-mail this MIT Test Data Form to EPA Region 14 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler/Tim Mayer Declined Jeff Jones /John Crisp Jerry Murphy PrudhtBay Unit, EPA Permit: AK -1I004 -A• OWDW Surveillance Procedures Background EPA permit AK- 1I004 -B effective December 08, 2009 requires an annual fluid movement test, Part II C 3 b (2). Notice of the proposed test schedule and the proposed test procedure was sent via email to Thor Cutler, EPA Region 10. The procedure specified a very similar technique to that used in previous tests. The Borax-PNL technique involves comparing pulse neutron log (PNL) passes run before and after pumping a solution of borax dissolved in warm water as a tracer. Borax is composed of hydrates of sodium tetraborate. Boron has an inherently high neutron capture cross section. A PNL indicates a significantly higher Sigma value when boron is present, so an overlay of log passes quickly indicates those areas within and adjacent to the wellbore where boron accumulates due to injection of the tracer. This technique is commonly used for cement channel detection in development wells on the North Slope of Alaska. A PNL, Schlumberger's RST (Reservoir Saturation Tool) is utilized for these surveys due to its availability at Prudhoe Bay and because it has been proven capable to detect the presence of boron laden fluids within and external to the wellbore. Borax-PNL Survey Procedure - EPA permit AK- 11004-B requires a fluid movement test "... be conducted at an injection pressures at least equal to the average continuous injection pressure observed in the previous 6 months ...". Injection into the OWDW wells is on an as needed basis, often with multiple short injection periods during each day. The average and maximum injection pressures are reported quarterly on EPA Form 7520-8. - Daily average and maximum daily injection pressures did not exceed 709 and 1062 psi respectively in that 6 month period. There was no injection in OWDW-SE during the 6 months prior to the tests. Wellhead pressures were 1000 psi or above for each well during the high rate pumping (4 to 5 barrels per minute) of borax solution. - The injection rate was reduced to minimum rate during individual log passes to minimize frictional drag on the logging tool due to high fluid velocities and small clearance between the tool (max diameter-- 1.72") and the tubing ID (1.995" in 2-3/8" or 2.441" in 2-7/8"). - In each well, the survey procedure involved the following steps: run baseline temperature and RST log pump 100 barrels hot water, high pump rate run RST baseline pass, minimum pump rate pump 30 barrels hot borax -water solution, high pump rate run RST pass, minimum pump rate pump 30 barrels hot borax -water solution, high pump rate run RST pass, minimum pump rate pump 15 barrels hot water at low rate to flush wellbore run final RST pass, minimum pump rate Page 1 of 2 Prudhoe Unit, EPA Permit: AK -1I004 -A OWDW Surveillance Procedures Optional Pump -in Temperature Survey Procedure Considerations To provide additional data if needed, an optional procedure was included in the procedure consisting of a series of three shut in temperature passes following the Borax-PNL survey operations to compare with the baseline temperature pass. The first pass was planned immediately after flushing borax from the well bore with hot water; the second was planned after 1 hour, the third after 2 hours, etc. Shut In temperature survey passes were made in the SW well to provide additional information. Michael L. Bill November 1, 2010 Page 2 of 2 Prudhoe Bay Unit, EPA Permit: AK-II004-A� OWDW Northwest (Pad -3 NW) Borax-PNL Survey Procedure - On 09/02/10 a slick line drift and tag run verified access to the NW well to 1992 feet MD. This is below the top of the perforations and assured sufficient interval was available to perform the survey - OWDW-NW injected normally during the previous six months. During that period, average and maximum daily injection pressures did not exceed 706 and 1034 psi respectively. Wellhead pressures during pumping were at or above 1000 psi. Borax-PNL Survey Results — reference OWDW-NW Schlumberger Reservoir Saturation / Borax Log — RST -E / PBMS-B, 24 -September -2010. Note: the depths referenced below refer to the Borax -RST log which was run with depths referenced to BGL (below ground level), as in RST logs from previous years. The wellbore schematic included in the log is referenced to RKB (reference Kelly bushing). The enclosed log trace includes pertinent individual passes. Each pass was run from the fill level to above 1500 feet MD. In addition, overlays of selected passes were prepared to compare the log response at various times during the survey. Each overlay contains the following traces: formation gamma ray (API units), casing collar locator, formation sigma (capture units), borehole sigma (capture units). - "100 BBL KCL and Base Overlay". Two baseline sigma passes were run, one before and after pumping about 100 barrels of hot water. The two baseline passes overlayed well; the initial baseline pass was used for comparison to subsequent passes. - "Borax #1 Pass and Base Overlay". This overlay shows the change in tool response between a baseline pass and a pass run after pumping the first stage of borax solution. During this pass borax solution was being pumped at minimum rate to minimize tool drag. The shading on the overlay indicates areas of increased sigma. Below the tubing tail, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the tubing tail, there is a small shift in wellbore sigma (1/4 to 1/z chart division) due to the small volume of borax solution surrounding the tool while it is in the tubing (Tubing ID=2.441", RST Tool max OD= 1.72"). There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. In fact, a small decrease of up to 1-1/2 chart division was noted in the formation sigma below the tubing tail. This is believed to an artifact of the processing algorithm. Typically, the increase in formation sigma due to the displacement of formation fluids adjacent to the wellbore with borax solution is 2-1/2 to 6 chart divisions or 5 to 12 capture units. "Borax #2 and Base Overlay". There is no significant change in the borehole sigma or in the formation sigma as a result of pumping a second stage of borax solution. " KCL Flush and Base Overlay". This overlay compares the tool response after flushing the boron laden fluid from the wellbore with water at low pump rates. The borehole sigma returned to baseline levels indicated the boron laden fluid had been flushed from the wellbore. This overlay also shows the statistical variation in the tool response and insures the tool is functioning properly. The absence of any significant increase in formation sigma after pumping a large amount of boron laden solution indicates there is no evidence of uphole movement of injected fluids above the bottom of the logged interval. Page 1 of 2 PrudhooBay Unit, EPA Permit: AK -1I004 -A• OWDW Northwest (Pad -3 NW) Baseline Temperature Survey - shown on log trace "Baseline Pres / Temp Pass", reference OWDW-NW Schlumberger Reservoir Saturation / Borax Log — RST -E / PBMS-B, 24 - September -2010. - The baseline temperature pass was run after the well had been shut in for about 12 hours to provide a basis for comparison should additional passes be necessary. It is similar in character to the baseline temperature surveys run in past years. These logs show significant permafrost warming due to vertical and radial heat transfer from injection operations from the perforations up to about 1650' MD. - Shut In temperature passes were not required due to the clear results from the Borax -RST passes. Overall Conclusions There is no indication of channeling uphole above the main injection interval. 2. Most, if not all, of the fluid pumped during the test was confined near the perforated interval. 3. These results are consistent with prior surveillance indicating injection probably takes place through a horizontal fracture within or near the perforations. There is a large area of reservoir permeability damage near the wells from past injection. (Ref. Section 6, UIC Class I Permit Application for the Pad 3 Injection Facility, submitted February 18, 1999). 4. This data and the annulus pressure test performed on 9/25/10 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Michael L. Bill November 1, 2010 Page 2 of 2 PrudhfoBay Unit, EPA Permit: AK -1I004 -A• OWDW Southwest (Pad -3 SW) Background - On 09/02/10, a slick line drift and tag run verified access to the SW well to 1981' MD feet. This is just below the top of the perforations and assured sufficient interval was available to perform the survey. - OWDW-SW injected normally during the previous six months. During that period, the average and maximum daily pressures did not exceed 709 and 1062 psi respectively. Well head pressures during pumping were above 1000 psi. Borax-PNL Survey Results - reference OWDW-SW Schlumberger Reservoir Saturation / Borax Log — RST -E / PBMS-B, 24 -September -2010. Note: the depths referenced below refer to the Borax -RST log which was run with depths referenced to BGL (below ground level), as in RST logs from previous years. The wellbore schematic included in the log is referenced to RKB (reference Kelly bushing). The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to above 1500' MD. In addition, sigma overlays of selected passes were prepared to compare the log response at various times during the survey. Each sigma overlay contains the following traces: formation gamma ray (API units), casing collar locator, formation sigma (capture units), borehole sigma (capture units). - "100 BBL KCL Over Base Overlay". Two baseline sigma passes were run, one before and one after pumping about 100 barrels of hot water. The first baseline pass was used for comparison to subsequent passes. - "Borax #1 Over Base Overlay" and "Borax #1 Over KCL 100 BBL". These overlays show the change in tool response between each baseline pass and a pass run after pumping the first stage of borax solution at pressures in excess of 1000 psi. During this pass borax solution was being pumped at minimum rate to minimize tool drag. The shading on the overlay indicates areas of increased sigma. Below the tubing tail, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the tubing tail, there is a small shift in wellbore sigma (1/4 to 1/z chart division) due to the small volume of borax solution surrounding the tool while it is in the tubing (Tubing ID=2.441", RST Tool max OD= 1.72"). There is a potentially significant increase in formation sigma (up to 2-3 chart divisions) in the interval 1798 to 1810', about 180 feet above the perforations. Typically, the increase in formation sigma due to the displacement of formation fluids adjacent to the wellbore with borax solution is 2-1/2 to 6 chart divisions or 5 to 12 capture units. Also, areas with high sigma values tend to have higher statistical variation due to the high capture of neutrons. A small decrease of up to 1-1/2 chart division was noted in the formation sigma below the tubing tail. This is believed to an artifact of the processing algorithm. - "Borax #2 Over Base Overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing, however the anomaly noted in the previous paragraph is still present at 1798 to 1810'. - "KCL Flush Over Base Overlay". This overlay shows the tool response after flushing boron solution from the wellbore with water at low pump rates. The wellbore sigma returned to baseline levels. There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing, however the anomaly noted in the previous paragraphs is still present at about 1798 to 1810'. There are no areas of a significant increase in formation sigma above or below this interval. - A similar but more pronounced anomaly was noted in the same interval on the final pass of a RST -Borax log run in this well on 9/25/09. A subsequent repeat log run on 11/07/09 did not show the anomaly and water flow log stops did not detect fluid movement behind casing. Page 1 of 2 Prudhtay Unit, EPA Permit: AK -1I004 -V OWDW Southwest (Pad -3 SW) Baseline Temperature Survey - log trace "Baseline Press / Temp". Reference OWDW-SW Schlumberger Reservoir Saturation / Borax Log — RST -E / PBMS-B, 24 -September -2010. - The baseline temperature pass was run to provide a basis of comparison for subsequent passes if needed. The baseline log is similar in character to past baseline temperature surveys. These logs show significant permafrost warming due to vertical and radial heat transfer from injection operations from the perforations up to about 1650' MD. - Shut In temperature passes were run to provide additional information on the formation sigma anomalies at 1798-1810' MD. Temperature passes were run immediately after pumping ceased then beginning at 1 hour intervals for a total of 4 post pumping temperature passes. - "Temperature Overlays". An overlay of the post pumping shut in temperature passes with the baseline gave no indication of upward fluid movement and did not confirm the anomalous formation sigma readings. The character of each pass was very similar and the rate of cooling back toward the baseline was consistent between passes. Leak Detection Survey Results, shown on log "PDS, Leak Detection - WLD 30 -Sep -2010". This log utilized the TecWel tool. The log confirmed tubing leaks at 850' and 1264' MD after the well failed an annulus pressure test on 9/25/10. Overall Conclusions: OWDW-SW 1. Anomalous formation sigma readings were observed in a small interval about 180 feet above the perforations on RST pass after pumping borax solution and flushing the wellbore with water. A more pronounced anomaly in the same interval was noted in the 2009 RST -Borax log. Subsequent logging did not detect fluid movement behind casing. 2. The sigma overlays did not show any indication of channeling from the perforations upward to the anomalous interval. 3. Post pumping shut in temperature passes showed no evidence of channeling adjacent to the wellbore and did not confirm the anomalous readings. 4. A Water Flow log may confirm or eliminate the anomalous readings. 5. Most, if not all, of the fluid pumped during the test was confined within or very near the perforated interval. 6. In general, these results (other than the anomalous intervals) are consistent with prior surveillance indicating injection probably takes place through a horizontal fracture within or near the perforations. There is a large area of reservoir permeability damage near the wellbore from past injection. (Reference: Section 6, UIC Class I Permit Application for the Pad 3 Injection Facility, submitted February, 18, 1999). 7. OWDW-SW failed an annulus pressure test on 9/25/10. Two tubing leaks were confirmed by leak detection logging on 9/30/10. Repair options are being explored. Michael L. Bill November 1, 2010 Page 2 of 2 Prudhtay Unit, EPA Permit: AK -1I004-0 OWDW Southeast (Pad -3 SE) Borax-PNL Survey Procedure - On 09/02/10, a slick line drift and tag run verified access to the well to 1979 feet measured depth (MD). This is at the top of the perforations and assured sufficient interval was available to perform the survey. - OWDW-SE had no injection during the previous six months. Wellhead pressures during pumping water were at or above 1000 psi. Borax-PNL Survey Results - reference OWDW-SE Schlumberger Reservoir Saturation / Borax Log — RST -E / PBMS-B, 23 -September -2010 0 - Revised Print 27 -Oct -10. Note: It was discovered that the original log prints reflected processing using an incorrect casing weight and a different wellbore size than has been used to standardize log presentations. The log was re -processed correcting these errors. The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to above 1500' MD. In addition, sigma overlays of selected passes were prepared to compare the log response at various times during the survey. Each sigma overlay contains the following traces: formation gamma ray (API units), casing collar locator, formation sigma (capture units), borehole sigma (capture units). - Two baseline sigma passes were run, one before and one after pumping 100 barrels of hot water at greater than 1000 psi wellhead pressure. Both baseline passes were used individually in the following overlays for comparison to subsequent passes. - "Borax 1 Over Baseline Overlay" and "Borax 1 Over KCL Overlay". These overlays show the change in tool response between each baseline pass and a pass run after pumping the first stage of borax solution. During this pass borax solution was being pumped at minimum rate to minimize tool drag. The shading on each overlay indicates areas of increased sigma from that baseline. Below the tubing tail, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the tubing tail, there is a small shift in wellbore sigma (1/4 to 1/2 chart division) due to the small volume of borax solution surrounding the tool while it is in the tubing (Tubing ID=1.995", RST Tool OD= 1.72"). Typically, the increase in formation sigma due to the displacement of formation fluids adjacent to the wellbore with borax solution is 2-1/2 to 6 chart divisions or 5 to 12 capture units. The largest formation sigma increase seen in either overlay was 2 to 2-1/2 chart divisions at 1955-60' MD, within the disposal interval. A small decrease of up to 1-1/2 chart division was noted in the most of the formation sigma below the tubing tail. This is believed to an artifact of the processing algorithm. - "Borax 2 Over Baseline Overlay" and "Borax 2 Over KCL Overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. - "KCL Flush / Baseline Overlay" and "KCL Flush Over KCL Overlay". These overlays show the tool response after flushing boron solution from the wellbore with water at low pump rates. The wellbore sigma returned to baseline levels. The largest formation sigma increase seen in either overlay was about 2 chart divisions. Consultation with a Schlumberger representative confirmed that these increases are within the anticipated statistical variation. The absence of any significant increase in formation sigma above the approved interval due to pumping a large amount of boron laden solution indicates there is no evidence of uphole movement of injected fluids. Page 1 of 2 0 0 Prudhoe Bay Unit, EPA Permit: AK -11004-A OWDW Southeast (Pad -3 SE) Baseline Temperature Survey — shown on Log trace "Press / Temp Baseline Pass, Up at 30 FPM", reference Schlumberger OWDW-SE Reservation Saturation / Borax Log, RST -E / PBMS - B, 23 -September -2010 - Revised Print 27 -Oct -10. - The baseline temperature pass was run after the well had been shut in for over 6 months to provide a basis for comparison should additional passes be necessary. It is similar in character to the baseline temperature surveys run in past years. These logs show significant permafrost warming due to vertical and radial heat transfer from offset injection from the perforations up to about 1650' MD. - Shut In temperature passes were not required due to the results from the Borax -RST passes. Overall Conclusions L There is no indication of channeling uphole above the approved injection interval. 2. Most, if not all, of the fluid pumped during the test was confined to near the perforated interval. 3. These results are consistent with prior surveillance indicating injection probably takes place through a horizontal fracture within or near the perforations. There is a large area of reservoir permeability damage near the wellbore from past injection. (Reference: Section 6, UIC Class I Permit Application for the Pad 3 Injection Facility, submitted February, 18, 1999), 4. This data and the annulus pressure test performed on 09/26/09 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Michael L. Bill October 19, 2010 Page 2 of 2 by 0 CERTIFIED MAIL # 7008 1830 0001 2703 8093 October 26, 2010 UIC Manager, Ground Water Protectic to U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 =I BP Exploration (Alaska) Inc. P. 0. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 Direct 907 561 5111 1 1' 1 RE: Third Quarter 2010- Pad 3 Injection Well Monitoring Repo" Ott: UIC Class I Permit AK - 11004-B e,,:: Dear UiC Manager: �fulfill �l 0ris being submitted tothe third quarter 2010 (July- September) reporting obligations for the above referenced permit. Enclosed are three forms [EPA 7520-8 (2- 84)] containing the information required by Part II, Section E of the permit. Also attached is a listing of the types and volumes of materials injected during the reporting period, a CD of the raw data, and graphs showing injection pressure, annular pressure, and injection volume for the wells. A description of the wastes managed at Pad 3 has been previously submitted to the EPA in the Waste Analysis Plan (WAP). The enclosed graphs and the raw data being submitted electronically on CD are a requirement under the Pad 3 UIC Permit (AK -1 1004-13). There are no permitted limits for the pH and temperature of the injected fluids. They are included in the reports as a physical description of the injected fluids (see Part 11, Section E (1)(b) of the permit). The pH values define the non -hazardous range allowed for non- exempt fluids injected and the temperature values define the range historically encountered. An annual demonstration of mechanical integrity is required by the Class I UIC permit. Annulus pressure tests were conducted in the NW, SE and SW wells on September 25. During the tests, the inner annulus pressure was recorded above the permit limit of 150 psi on the NW and SW wells. No injection was taking place during these tests. Logs were also run in the three Pad 3 wells on September 23 and 24 as part of the demonstration. The results of these tests and logs will be submitted under a separate cover. OWDW-SW remains shut-in after failing its annulus pressure test. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. UIC Manager • • July 22, 2010 Page 2 If you need any clarification or additional information concerning these reports, please contact Alison Cooke, at (907) 564-4838 or Alison.Cooke@bp.com. Sincerely, a Kathy Fontaine Logistics/Infrastructure Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC 10 9 UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2010 Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum MONTH MONTH MONTH July August September 0 382 0 575 572 522 910 1,034 873 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 101 91 89 111 110 109 142 140 142 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 30 0 40 39 39 67 61 176 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 2,297,938 1,933,256 1,195,345 12,595,414 14,528,669 15,724,014 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 PH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Ma)dmum Daily Injection Volume Gallons/Da 74,127 61,303 39,845 135,488 133,287 91,069 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.Q. BOX 196612 ANCHORAGE, AK. 99519 - 6612 Permit Number NW Well ADEC 9821 - DB001 EPA Well Permit No. AK - 11004A Name and Official Title Signa re Date Signed Kathy Fontaine {Logistics/Infrastructure Manager EPA FOnn 15ZU64 (2-54) *The values provided define the non - hazardous range and are not measured values . See Waste Analysis Plan. Values in parentheses ( ) are actual values for permit compliance 0 a UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2010 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum July August September 0 381 0 614 609 550 974 1,062 924 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 99 93 0 110 110 87 141 139 142 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 46 0 57 57 51 93 83 203 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 2,302,688 1,938,363 1,064,969 12,151,772 14,090,135 15,155,104 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 PH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons(Da 74,281 61,290 35,499 136,534 133,287 92,093 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SW Well ADEC 9821 - D6001 EPA Well Permit No. AK -11004A Name and Official Title Kathy I'ontaine Log istics/lnlrastructure Manager S gnature Date Signed cr-r% rurm I DAU-a tA-04) I The values Provided define the non - hazardous range and are not measured values. See Waste Analysis Plan. Values in parentheses ( ) are actual vahres for permit compliance . UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EFTA INJECTION tii'wiELL MONITORING REPORT YEAR 2010 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum July August September 0 253 0 264 273 117 283 304 808 Injection Rate (Gal/Mtn) 1. Minimum 2. Average 3, Maximum 0 0 0 0 0 15 0 0 112 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 15 0 15 15 22 16 16 88 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 0 0 116,926 0 0 116,926 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 0 0 3,898 0 0 52,798 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SE Well ADEC 9821-DB001 EPA Well Permit No. AK -11004A Name and Official Title Kathy Fontaine Logistics/Infrastructure Manger S gnature Date Signed EPA Form Tbz" (Z -a4) • The values provided define the non -hazardous range and are not measured values. See Waste Analysis plan. The values In parenthesis ( ) are actual values for compliance purposes . 12000C 10000C E:Z�Z�Z�Z T 6000C ea m 4000C 2000C C Total Well Volumes �O 20 �o �O �o �O 4T 4r, �O �o �O �o Days Total Volume Injected n U n .y a Maximum Injection Pressure 1600 1400 - - 1200 - - - - - - - -- - - ----- - - -- - - -- - . .. - - - -- - - - -- - - - 1000 --- - - - -- 800 600 -- - - - - - - - - - -- - _ . -- - - - 400 - -- - - -- - -- - ---- - -- -- 200 -- - ----- -- -- --- ----- - --- - - -- ---- -- - - -- -- -- - 0 . do pyo �o �0 20 �o 15\T 4F �o �o �o �0 20 �o �0 20 �o A ��\ \o'\ \'`,�\ \'`15\ 1 \'`4\ 1 \'`A\ \'`o,\ \ .1\ \ 4 \ 4'\ \A\ \ o,\ \ I"\ 1 1 1 Irl' '1Cl' 'kr' 'kr' Irl' 1r�l Days - NW SW SE IL - Limit 0 0 .y a Maximum Annular Pressure 160 140 120 100 80 60 40 20 0 O �o pyo do �o do pyo To do To pyo To �o To �0 20 �o '1\ 0,\ �\ \'` 3\ \'`�\ \��\ moo,\ �\ �\ �\ .�\ o,\ �\ 1\�1\ 1 1 1\ 12A\"- 1\� 1\Cl 1T\ 1\Cb Days NW SW — SE Limit 0 10000C 9000C 8000C 7000C 6000C 5000C m 4000C 3000C 2000C 1000C C Total Well Volumes �O TO TO r,O TO r,O PO TO rl-O PO JO �O P -O TO 9O JO (81�5 � � � �2 �2 C J (JL C`L \rb Days Total Volume Injected 0 0 .N a Maximum Injection Pressure 1600 1400 1200 - - - - - — -- --- -- - - - - ---- - - 1000 - - - - - - - - -- - - -- 800 - - -- - --- - -- _ _- _ _ --------- --- 600 -- - - - 400 200 0 O O 40 4T O X20 ATO )TO ATO ATO F ATO ATO ATO ATO ATO ATO (b\rl J J J (b\rl 41 Days - _NW i SW SE I Limit •I • a Maximum Annular Pressure 160 140 - - -. -- - - - - --- - - - --- -- __ - - 120 _ - -- ---- -- - ----- - _ - -- ._ --- - - --- - -_. -- - - 100 80 60 20 - - - - -- - - _ --- ---- --- - - - - - - -- -- - _. __ -- - - 0 - �O �O �O �Q �O �O �O 26 �O �O �O 20 �O �O �O �O �\�\ ��\ �\�\ \�N\ \�3\ \��\ \�.�\ \moo,\ \ ,�\ \ �\ \ �\ \A\ \ o�\ \ N\ � � � �� �2 J\ �� �� 4 Days -N W SW --SE � Limi( •� is 50000 U11111Z T i 3000C �a m 2000C 1000C 11 Total Well Volumes \�O \TO 0 \TO \�O \�O \�O \TO \TO \�O \rO \T \1P \�O \rc \�O C\ O\O C§ O\1 O\O l' \�3 lam\ l� \ \`, \�O \`L� \PA\`LO O O O O O O O 0 O 0 Days Total Volume Injected • 1600 1400 1200 1000 CL 800 600 400 200 0 \gyp \gyp \�O \�O \�O \20 \20 \�O \20 \�O \�O \�O \TO T \TO Days Maximum injection Pressure 1 NW SW SE Limit r�L • 25( 20( Maximum Annular Pressure »1 0! Q) OHO IQ) I X20 ATO ATO ATO PO ATO ATO ATO ATO ATO 0 C C 4 COI C 4 Days NW SW SE Limit Pad 3 - Injection Composition Summary 0710112010 to 09/30/2010 By Component • 0 by North Slope Technical Services �eR Equipment Services Group Component Barrels Acid 77.50 Ammonium chloride 99.90 Arctic Pac 346.50 atc firefighting foam 136.00 Boiler Blowdown 525.00 cellar box fluids 20.00 Cement rinsate 225.00 Cement/Contaminate 5,173.43 Chemclear 1.75 Chromium acetate 0.10 class 1 rinsate 14,095.00 class 1 sump fluids 741.00 class 2 fluids 1.00 class 2 rinsate 13,048.00 Class 2 Sump Fluids 136.00 class 1 rinsate 285.00 cleaning fluid 1.00 completion fluids 132.90 Corrosion inhibitor 2.90 Crude Oil 9,505.25 Diesel 1,928.81 Diesel/Water Gel 744.79 Domestic Water 1,977.00 Drilling Mud 13,042.15 Drum rinsate 30.00 equipment/facility wash water 1,375.00 Frac Sand 142.90 freeze protect / down hole 3.00 Fresh Water 65,901.25 Glycol 200.63 Gravel/Sand 73.73 Generafe0✓srg AaaS 2--M.WIFF.--Rev ZSD Printed on Thursday, October 21, 2010 Page 1 of 3 0 Peck 3 ® injection by Composition Summary North Slope Technical Services 0710112010 to 0913012010 Equipment Services Group 0 By Component Component Barrels lathe coolant 55.00 Line pigging solids 137.50 Methanol 485.74 Mineral oil 38.10 mobm 2.00 non haz soap 1.25 oil based mud 43.30 Photo processor fluids 53.00 pigging fluids 85.00 Pigging Returns 0.36 Pigging Solids 0.83 pit water 2,430.00 Produced Water 18,152.86 rain water 143.00 Rain/Storm water 906.00 rainwater 543.00 rainwater/snowmelt 350.00 remediation fluid 45.00 reserve pit fluids 175.00 Reserve/Flare/Relief Pit Water 930.80 Rinsate 2,413.30 rinsate (Class 1) 580.00 sand 0.12 SANDJETTING SOLIDS 2.00 SAPP 348.00 Scale/Corrosion Inhibitor 0.48 SCHBOO B GONE 18.90 schmoo b gone 5.10 Seawater/Brine/KCI 42,678.90 snow melt 3,415.00 Snowmelt 9,942.00 Generaetl usag Accass 2000-MarpHslFE.m00 Ae 2.SD Printed on Thursday, October 21, 2010 Page 2 of 3 Fuad 3 - injection by Composition Summary North Slope Technical Services 07/01/2010 t'® 0913012010 Equipment Services Group By Component Component Barrels snowmelt/ponded water 336.00 snowmelt/rainwater 4,294.00 Soap 5.59 Soda ash 1,935.60 soda ash solution 128.50 Source Water 211.50 SPILL CLEANUP MATERIAL 905.00 Spill Cleanup Waste 3,776.00 Storm Water 16,839.00 Sump fluids 3,876.88 sump fluids / snowmelt 440.00 TEG 3.00 Used Oil 1.00 wash waters 193.00 washing machine water 143.50 well cellar fluids 800.50 WR6 Soap 4.72 Total Volume: 247,847.81 Gerr W—VA —1000-MaW-FE. 1b -Re PSD Printed on Thursday, October 21, 2010 Page 3 of 3 AOGCC MITIA Forms for GNI-02Aif61190), GNI-03 (1971890), GNI-04 (i 1170), OWD... Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, October 01, 2010 9:15 PM 71ee' 'T 10/6/10 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: AOGCC MITIA Forms for GNI-02A (2061190), GNI-03 (1971890), GNI-04 (2071170), OWDW-NW (1002400), OWDW-SE (1002390), OWDW-SW (1002380) Attachments: Sept 2010 MIT Forms #2.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: GNI-02A PTD #2061190 GNI-03 PTD #1971890 GNI-04 PTD #2071170 OWDW-NW PTD #1002400 OWDW-SE PTD #1002390 OWDW-SW PTD #1002380 A copy of the EPA MIT form is included also. <<Sept 2010 MIT Forms #2.zip>> Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 10/6/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test • Submit to: iim.reggCcDalaska.gov: doa.aogcc.prudhoe. bavCrDalaska.gov: phoebe.brooks@alaska.gov: tom.maunder(cbalaskaa.gov OPERATOR: BP Exploration (Alaska), Inc. ` folb f jo FIELD / UNIT / PAD: Prudhoe Bay / PBU / OWDW 1 J DATE: 09/25/10 OPERATOR REP: Jerry Murphy AOGCC REP: Declined witness Jeff Jones/John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. P = Standard Pressure Test Well OWDW-N Tye In'. I N TVD 1,900' Tubing 426 427 432 429 Interval 0 P.T.D. 1 1002400 1 Type test I P Test psi 1500 Casing 17 1515 1409 1385 P/F P Notes: MIT -IA for annual regulatory compliance OA Witnessed by EPA representative Thor Cutler Well OWDW-SE Type In'. I N I TVD 1 1,885' Tubing 309 313 307 307 Interval 0 P.T.D. 1002390 1 Type test I P I Test psi 1500 Casing 1,4441 1,420 P/F I P Notes: MIT -IA for annual regulatory compliance OA Witnessed by EPA representative Thor Cutler _1__1,131 Well WDW-S"peN TVD '1,902' Tubin 525 525 Interval 0 P.T.D. 1002380 P Test psi 1500 Casing 25 1,500 P/F F Notes: IA pressure fell off at 200 psi/min I OA Witnessed by EPA representative Thor Cutler Well I Type In'. I I TVD I Tubing Interval P.T.D.1 I Type testl I Test psi I Casing P/F Notes: OA Well I TypeInj.1 TVD Tubing Interval P.T.D.1 I Type testl I Test psi I Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test Form 10-426 (Revised 06/2010) MIT PBU OWDW-NW OWDW-SE OWDW-SW 09-25-2010.x1s INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility I Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-SW AK -1I004 -A 1002380 Injector MIT Type Test Type Test Date Class I T X IA I Std. Annular Pressure Test (SAPT) 9/25/2010 Req'd Test Presssure (psi) Fluid Type(s) used to test Packer Depth (ft, TVD) Test Interval / Comments 1,500 Diesel 1,902' 0 Yearc,ycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T E S T START TIME: 6:10 PM PREMIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT P/F FAIL TUBING 525 525 INNER ANNULUS 25 1500 OUTER ANNULUS 1 COMMENTS: IA pressure fell off -200 psi per minute during multiple tests Load IA w/ 2.1 bbls diesel; 0.3 bbls to pressure up T E START TIME: 7:12 PM PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT S T TUBING 525 525 FAIL INNER ANNULUS 0 1550 OUTER ANNULUS 2 COMMENTS: IA pressure lost —200 psi in less than one minute T E START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT S T TUBING PASS/ FAIL INNER ANNULUS OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: Last test MITIA -09/26/09 (witness T. Syed/T.Cutler/B.Noble), Borax-PNL/temp survey - 09/24/10. Originally drilled in the 1970s to test the thaw characteristics of permafrost. IA to 1505 psig on 0926/09. Loss was 115 psi after 15 min and additional 20 psi for a 135 psi total loss after 30 min (less than 10' NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). 0 -- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: ✓ Operator Rep: Thor Cutler/Tim Mayer Declined Jeff Jones / John Crisp Jerry Murphy NOT OPERABLE: Injector OWDW-SW (PTD #1002380) Failed MITIA During Annual is is Maunder, Thomas E (DOA) . Page 1 of 1 From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Sunday, September 26, 2010 4:05 PM To: cutler.thor@epa.gov; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS Waste PAD 3 (AES); AK, OPS Roads Pads & Remediation TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; Bill, Michael L (Natchiq) Cc: King, Whitney; Holt, Ryan P (ASRC); AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Injector OWDW-SW (PTD #1002380) Failed MITIA During Annual Surveillance Attachments: Injector OWDW-SW (PTD #1002380) TIO and Injection Plot.doc; Injector OWDW-SW (PTD #1002380) wellbore schematic.pdf All, Injector OWDW-SW (PTD# 1002380), a class 1 EPA disposal well, failed a MITIA on 9/25/2010 to 1500 psi during the annual surveillance witnessed by EPA representative Thor Cutler. The failing MITIA indicates the lack of two competent barriers to pressure in the wellbore. The well was not on injection during the pressure testing, and shall remain shut-in from injection pending further investigation. The current plan forward is to evaluate with a leak detect log, then evaluate repair options pending the results of the logging. A TIO and injection plot and wellbore schematic have been included for reference. <<Injector OWDW-SW (PTD #1002380) TIO and Injection Plot.doc>> <<Injector OWDW-SW (PTD #1002380) wellbore schematic.pdf>> Please call with questions or concerns. Gerald Murphy (alt. Torin Roschinger) S� Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 _ Z Pager (907) 659-5100 Ext. 1154 9/27/2010 i 0 Injector OWDW-SW (PTD #1002380) TIO Plot W.R OWDW-SW 301 W 10 Injector OWDW-SW (PTD #1002380) Injection Plot WAL DwDW-6W 700 650 600 550 500 450 ,400 3 350 300 250 200 150 100 50 a "Co 42(0 4 U00 3800 3600 3, 40 3 200 3 BW 2,800 2 6CU m "400 2CO 3 '000 1,800 0 t,F,00 t,aw 1.200 1,000 800 600 400 200 0 # Tbg -NF-w DA DOA D00A on TREE = 2-9/16" CIW WELLHEAD= FMC ACTUATOR= Note: Refer to Production DB for historical perf data KB. ELEV = 56.5' BF. R EV - 32 KOP = _ 0 Max Angle = 0 Datum MD = 10/19/06 Datum TV D = 13-3/8" CSG, 72#, N-80, ID = 12.347" 1 Minimum ID = 2.205" @ 1928' 2-7/8" HES XN NIPPLE 12-7/8" TBG, 6.5#, L-80, EUE, .0058 bpf, ID =2.441" 1-1 1941' PERFORATION SUMMARY REF LOG: DIL ON 06/25/73 ANGLE AT TOP PERF: 0 @ 1980' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 1980-2005 O 10/19/06 PBTD I-1 2134' 5-1/2" CSG, 17#, L-80, ID = 4.892" 2215' TD — SNOTE OILY WASTE DISPOSAL WELL. C CT MIKE BILL PRIOR TO DOING ANY DOWNHOLE WORK . SOME LOGS ARE MEASURED FROM GROUND LEVEL. "2006 RWO: DEPTHS ARE REFERENCED TO RKB, RKB TO GL = 33' "LOWER FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY " 3-1/2" OTIS TREE CAP CONNECTION 3/8" CONTROL LINES, I OPEN ENDED w /CHECK V LV S 1879 (-� 2-7/8" HES X NIP, ID = 2.313" 1900 -1 SEAL LOC SUB, ID = 2.410" 1901 BKR GBH -22 LOC SEAL ASSY, ID = 2.370" 1902 2-7/8" BKR F1 PROD PKR 01/01/85 w / SEALBORE EXT, ID = 3.00 1928 2-7/8" HES XN NIP, ID = 2.205" 1941 -12-7/8" WLEG, ID = 2.441" 1908 ELMD LOGGED (11/07/06 RST/ CDL) 2070' 1--1TOPOF FILL (11/07/06) DATE REV BY COMMENTS DATE REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 12/13/06 BJMC1PJC DRLG DRAFT CORRECTIONS 01/01/85 RWO 10/22/07 JD/PJC NOTE: TREE CAP CONNECTION 11/12/06 D16 RWO 05/31/06 DTM WELLHEAD CORRECTION 10/19/06 1 RDBIPAGI SANDBACK / CMT CAP 11/16/06 JMC/PAG RMV SLUGGITS / PULL PLUG PRUDHOE BAY UNIT WELL: OWDW-SW PERMIT No: 00-238 API No: 50-029-21817-00 SEC 11, T1 ON, R1 4E, 1064 FEL, 668 FNL BP Exploration (Alaska) Maunder, Thomas E (DOA) From: Cooke, Alison D [Alison.Cooke@bp.com] Sent: Thursday, September 23, 2010 9:34 AM 0 Page 1 of 1 goo-a��s a= To. Maunder, Thomas E (DOA) Subject: RE: 2Q Pad 3 EPA Report Tom, I thought I sent you this reply. Sorry for the delay. We will make sure the next report is corrected. Thanks for catching the inconsistency. Alison From: AK, HSSEE Env Adv Central Sent: Monday, August 30, 2010 9:25 AM To: Cooke, Alison D Cc: Bill, Michael L (Natchiq) Subject: RE: 2Q Pad 3 EPA Report Alison, There is no difference between the two, so total stormwater for the period would be a sum of the two (it is just that one operator started to enter under Stormwater, and the other entered under storm water not knowing the other category was intact. Todd Todd Winkel/Bryan Collver BP AK Environmental Advisor Central Office - (907) 659-5893 Pager -(907)659-5100 #2675 Harmony - 758-2332 From: Cooke, Alison D Sent: Wednesday, July 28, 2010 12:11 PM To: AK, HSSEE Env Adv Central Cc: Bill, Michael L (Natchiq) Subject: FW: 2Q Pad 3 EPA Report Todd and Alex, Can you comment on this please. Do we need to make a change to the form? Thanks, Alison From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 27, 2010 8:41 AM To: Cooke, Alison D Subject: FW: 2Q Pad 3 EPA Report Alison, I was examining the 2Q Pad 3 report that was copied to the Commission and had a question. In the Composition Summary listing, what is the difference between "storm water" and "stormwater"? There are separate listings for each with roughly the similar volume totals for each. Thanks in advance for your reply. Tom Maunder, PE AOGCC 9/27/2010 x • bp t—, F ED Alaska W & Ga; C40. $Sion Certified lirdlail # 7008 3230 0000 2496 4389 Alic3i tt'3p BP Exploration (Alaska) Inc P. 0. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 July 22, 2010 Direct 907 561 5111 __T UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 RE: Second Quarter 2010 — Pad 3 Injection Well Monitoring Report UIC Class I Permit AK —11004-B 1()O— Dear UIC Manager: ►o©-- D'�"Zk goo a ---k k-) This report is being submitted to fulfill the second quarter 2010 (April -June) reporting obligations for the above referenced permit. Enclosed are three forms [EPA 7520-8 (2- 84)] containing the information required by Part II, Section E of the permit. Also attached is a listing of the types and volumes of materials injected during the reporting period, a CD of the raw data, and graphs showing injection pressure, annular pressure, and injection volume for the wells. A description of the wastes managed at Pad 3 has been previously submitted to the EPA in the Waste Analysis Plan (WAP). The enclosed graphs and the raw data being submitted electronically on CD are a requirement under the Pad 3 UIC Permit (AK -1 1004-B). There are no permitted limits for the pH and temperature of the injected fluids. They are included in the reports as a physical description of the injected fluids (see Part II, Section E (1)(b) of the permit). The pH values define the non -hazardous range allowed for non- exempt fluids injected and the temperature values define the range historically encountered. On April 12`h a maintenance test was performed on the Barrel totalizers of the Northwest (NW) and Southwest (SW) Wells. This annual check required that the injection process be shut down and a signal simulating injection was then used to verify the accuracy of the counter; as a consequence the volumes for these wells were recorded higher than the actual volume injected. 95 BBLS for the NW well and 427 BBLS for the SW well were subtracted from the well totals. These subtractions are reflected in the attached graph for April 2010. A note has been added to April 12th's daily data file on the attached CD. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. • 0 UiC Manager July 22, 2010 Page 2 If you need any clarification or additional information concerning these reports, please contact Alison Cooke, at (307) 564-4838 or Alison. Cooke@bp.com. Sincerely, Kathy Fontaine Logistics/Infrastructure Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC • UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT 2010YEAR Injection Pressure 1) 1. Minimum 2. Averdge 3. Maldmu a 2 MONTH G -may June 418 0 0 582 556 636 817 877 818 Inpection Raft ( ) 1. Minimum 2. Average 3. Maximum Permit Nloa liber BP EXPLORATION (ALASKA. INC.) 93 97 82 108 110 115 210 144 143 Annular Pressure p 1. Mkdmum 2. Average 3. Maedmum Nlmreee and Official Tide otamtare 32 0 0 42 38 35 58 58 51 I ( 1. Monthly Total 2. Y2Eq Cumulative 1,582.476 1,556,604 3,585,830 5,145,042 6.701,646 10,287,476 Tempembffe (h') 1. Minimum 2. Average 3. Ma)dmum 35 35 35 50 50 50 130 130 130 1. Minimum 2. Average 3. Maxhmm 2 2 2 7 7 7 12.5 12.5 12. 1. Monthly Average l*cdon Vdume (Gal ) 52,752 50,232 118,w8 2. Mwftm Dally Vdkxne 118,574 142,380 176.568 Monte and Addrew of PermKine Permit Nloa liber BP EXPLORATION (ALASKA. INC.) NWW9111 1®®-- 800 E. BENSON BLVD. ADEC 9621 - DB001 P.O. BOX 196812 EPA Well Permit No. ANCHORAGE AK. 89518 - 6612 AK -11004A Nlmreee and Official Tide otamtare DaftSigned Kathy Fontaine Logistics/Infrastructure 7 ?� +1✓LE! -iA Manager / 'no Valles pwjxW d@FA do nm - femdaue raige and are not mseeu ml Yaltm . See VYWW A nalp IC Plan. Value in pawdumm ( ) In ach valise fa pennR complience M M ki w w UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2010 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum April May June 337 0 0 611 163 655 802 189 788 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 94 97 92 108 110 113 212 142 142 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 43 0 0 56 16 49 76 16 70 InjeWon Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 1,592,262 1,560 216 3,573,486 4,715,382 6,275,5W 9,849,084 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 PH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume(Gallons/Day) 53,088 50,316 119,112 112,980 1 143,850 178,878 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 198612 ANCHORAGE, AK. 99519-6612 Permit Number SW well vd ADEC 9621 - DB001 EPA Well Permit No. AK - 11004A Name and Official Title Kathy Fonine ta Logistics/Infrastructure Manager Si nature %/� /J6 Date Sim EPA Form 7=4 (2-84) ° The values provided define the non - hazardous range said are not rrasraed values. See Waste Anahm z Pin . Vakras h permtheses ( ) are avast vakies for pemrfi amplance . UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPI' INJECTION WELL MONITORING REPORT 2010 MONTH MCMTH MOWrK Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum I ft .lune 125 0 0 163 163 229 178 189 353 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Ma)dmum 15 0 0 16 16 16 17 16 20 Injection Volume (Gail) 1. Monthly Total 2. Yearly Cumulative 0 0 0 0 0 0 Temperature (F) 1. Minimum 2. Average 3. Maxim= 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume 0 0 0 0 0 0 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SE Well V) ADEC 9821-DB001 EPS` Well Permit No. K-1I004A Name and Otiicial Title Kathy Fontaidi8 Logistics/Infrastructure Manager Signature Date SWed EPA Form 7820.6 (2-84) The vAm p degree Cee nwownfffto rind and an nd memmW vWM . See Waste Analysis Om . The vahm in parcw#mn is ( ) are actual values for aomtr" purpows . E n L� 30000 70000 60000 50000 �s 40000 30000 20000 10000 0 0000.....0 p® Os) \`L® \`L��Cj ,sj N�) N(�� Nsi Ns-� N(Z) NCJ Nsi Ns� N(J. N(3 N(3 Days Total Volume Injected 0 G 10 160 140 120 100 80 60 40 20 0 Maximum Annular Pressure 4(p arp 4cp Days —NW SW SE Limit 0 10 1 600 1400 1200 1000 800 600 400 200 0 Maximum Injects®n Pressure \�O � Days —NW i SW SE — Limit 0 70000 F-7 LJ 60000 50000 40000 30000 20000 10000 0 �O �O TO �O rp P (p f p CP p 20 Total Well Volumes —Total Volume Injected E li 180000 160000 140000 120000 2 100000 IM 80000 60000 40000 20000 0 __._._�_------.-- \20 Days Total Volume Injected • 1 0 Maximum Annular Pressure 160 140 120 100 80 60 40 20 0 O O O O O O X20 \�O O O Days NW SW --SE Limit 40 .N a 10 1 600 1400 1200 1000 800 600 400 200 0 Maximum Injection Pressure 0� 0� X� Days —NW SW SE — Limit • 160000 0 14000C 120000 100000 80000 60000 40000 20000 0 Total Well Volumes NO NO NO NO Ns� NO NO NQ) ,O NO NO NO bN�, b,` b\,, \� \ `r1 \N\T(,o \` ,A\T b\CL`s Days Total Volume Injected n LJ a 10 160 140 120 100 80 60 40 20 0 Days I—NW SW — SE Limit CL 00 1400 1200 1000 600 600 400 200 0 M8XIMUM Injection Pressure O O O O\ O\ O\ O\`L O\`1; O\`L O\T Days i --SW SE Limit 0 Rad 3 - Injection Composition Summary 04101/2010 to 06/30/2010 By Component • North Slope Technical Services Equipment Services Group Component Barrels Acid 73.21 aqueous basic lab waste 1.00 Arctic Pac 359.25 arctic pack 2.85 Boiler Blowdown 384.50 cellar box fluids 385.00 Cement rinsate 200.00 Cement/Contaminate 5,587.85 Chemclear 1.00 class 1 rinsate 12,418.05 class 1 sump fluids 1,094.00 class 1 well cellar fluid 78.00 class 2 rinsate 11,400.22 Class 2 Sump Fluids 20.00 Crude Oil 4,236.80 Cuttings 165.00 Diesel 3,465.49 Diesel/Water Gel 1,474.09 Drilling Mud 9,647.30 Drum rinsate 54.00 exempt spill cleanup 338.00 Expired Medication 0.02 Fresh Water 64,831.89 Glycol 77.52 Hydraulic fluid 2.00 hydrogen peroxide & water 1.00 Hydrotest Fluid (water) 368.00 kitchen cleaning fluids 4.00 lathe coolant 15.00 Line pigging solids 1,035.03 Methanol 873.70 Printed on Saturday, July 03, 2010 Page 1 of 3 In°t0 C1, A n v Pad 3 - Injection Composition Summary 04/01/2010 to 06/30/2010 By Component Component Mineral oil NH4CL non haz soap off spec product Photo processor fluids pigging fluids Pigging Solids Ponded Water Produced Water rain water Reserve/Flare/Relief Pit Water Rinsate Santrol Super Set P SBG Scale/Corrosion Inhibitor Seawater/Brine/KCl sewage snow melt SNOW MELT WELL CELLAR snow melt/ponded water Snowmelt snowmeWponded water snowmeWrainwater Soap soapy water Soda ash soda ash solution SPILL CLEANUP MATERIAL Spill Cleanup Waste Spot clean up waste storm water C -..W w:yA-WW. M.M-WF,M0-An.Z5b Printed on Saturday, July 03, 2010 North Slope Technical Services Equipment Services Group Barrels 78.50 5.19 2.30 290.00 3.00 66.00 0.25 2.00 12,803.57 60.00 80.00 1,690.00 58.94 6.40 0.85 52,243.37 2.00 15,740.60 35.00 870.00 36,015.25 345.00 206.00 16.27 116.00 1,308.20 397.25 2,853.00 7,745.00 545.00 21,176.00 Page 2 of 3 %"I.37 0 Sa.L-10 %i."1"20 G 41� 7V ,`Pad 3 - Injection Composition Summary 04/01/2010 to 06/30/2010 By Component Component stormwater Sump fluids Turbine washwater u67 Used oil washing machine water water well bore fluids well cellar fluids well celler fluids Total Volume: G.,r,Yww,yaawxvo• .m®-Rw2.5b Printed on Saturday, July 03, 2010 0 North Slope Technical Services Equipment Services Group Barrels 20,524.00 4,426.00 0.11 8.65 0.35 11.50 210.00 10.00 8,559.70 62.00 307,167.02 Page 3 of 3 Certified Mail # 7006 3230 0000 2496 4310 ja 2 � 2010 (r rat7GKs� � � 17.%?. IJ43illl� oi�Si®:! July 21, 2010 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Re: Demonstration of Mechanical Integrity, Prudhoe Bay Pad 3, UIC Class I Permit AK -1 1004-B Dear Mr. Kowalski: BP Exploration (Alaska) Inc P. 0. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 Direct 907 561 5111 This letter is to submit the results of recent tubing inspection logs in UIC Class I wells OWDW-NW, SW and SE. These wells are located at Pad 3 in the Prudhoe Bay Unit and are operated by BP Exploration (Alaska), Inc. (BPXA). The tests are specified as part of the demonstration of mechanical integrity under Part 11, C.3 b (3) of EPA UIC Class I permit AK11004-B. The enclosed descriptive and interpretive report contains the results for the following logs and tests as required under Part II, C.3.c(1) of the permit: - Tubing Inspection Log: OWDW-NW, June 10, 2010 - Tubing Inspection Log: OWDW-SW, June 10, 2010 - Tubing Inspection Log: OWDW-SE, June 11, 2010 There was no indication of a loss of well integrity. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, Katharine Fontaine Logistics and Infrastructure Manager Attachments Cc: Thor Cutler, EPA Region 10 (letter and report) Talib Syed, EPA Consultant (letter and report) Jim Regg, AOGCC (letter and report) Shawn Stokes, ADEC (letter and report) Demonstration of Mechanical Integrity Prudhoe Bay Grind and Inject Project Well OWDW-NW, SW, SE EPA permit AK- 11004-B effective December 8, 2009 requires a tubing inspection log in the Prudhoe Bay Unit Class I Pad 3 wells once every two years. Approved tubing inspection logs (Part H C 3 b (3)) include pipe analysis logs, caliper logs or other equivalent tests. Below are the results of calliper logs run recently in the three Pad 3 wells: OWDW-NW, SW, and SE. Tubing Inspection Log_ A memory caliper log was run in wells OWDW-NW, SW and SE on June 10-11, 2010. The 24 arm caliper logging tool, supplied by PDS (ProActive Diagnostic Services), was run on slickline to inspect the interior surface of the tubing. The tubing inspection indicated the tubing in OWDW-NW and SW to be in fair to poor condition due to isolated pitting corrosion. The tubing condition in OWDW-SE is in good to fair condition. There is verly little general cross sectional metal loss (18% or less). The OWDW-NW and SW tubing strings was replaced during workovers in 2006. Enclosed are copies of the PDS Memory Multi -Finger Caliper, Log Results Summaries for the three wells. Below are the observed maximum metal losses observed in the tubing from the caliper logs. OWDW Well Date Maximum Pit Penetration Max Cross -Sectional Wall Loss NW Tubing 06/10/10 48% <15% SW Tubing 06/10/10 50% <12% SE Tubing 06/11/10 37% 18% Overall Conclusions The OWDW-NW, SW and SE caliper logs indicate the tubing in each well has corrosion damage but is suitable for continued injection. Michael L. Bill July 07, 2010 �vl�j - M 113 - bp �. %p Certified Mail # 7008 1830 0001 270. BF Exploration (Alaska) Inc. P O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 Direct 907 561 5111 April 20, 2010 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) per -, 1200 Sixth Avenue, Suite 900 * . Seattle, WA 98101 RE: First Quarter 2010 - Pad 3 Injection Well Monitoring Report UIC Class I Permit AK - 11004-B e�,3'6 D .rte Dear UIC Manager: This report is being submitted to fulfill the fourth quarter 2010 (January - March) reporting obligations for the above referenced permit. Enclosed are three forms [EPA 7520-8 (2-84)] containing the information required by Part II, Section E of the permit. Also attached is a listing of the types and volumes of materials injected during the reporting period, a CD of the raw data, and graphs showing injection pressure, annular pressure, and injection volume for the wells. A description of the wastes managed at Pad 3 has been previously submitted to the EPA in the Waste Analysis Plan (WAP). The enclosed graphs and the raw data being submitted electronically on CD are a requirement under the Pad 3 UIC Permit (AK -1 1004-13). There are no permitted limits for the pH and temperature of the injected fluids. They are included in the reports as a physical description of the injected fluids (see Part II, Section E (1)(b) of the permit). The pH values define the non -hazardous range allowed for non- exempt fluids injected and the temperature values define the range historically encountered. On January 7, 2010 the Southwest well recorded a maximum injection pressure greater than the 1400 psi permit limit. The exceedance occurred during trouble shooting and testing of the well's pressure sensing equipment which caused a high pressure reading of 2017 psi. On March 9, 2010 the Southeast well recorded a maximum annulus pressure greater than the permit limit of 150 psi and a max injection pressure greater than the permit limit of 1400 psi. The reason for this exceedance was due to preventative maintenance performed on the pressure sensing equipment, which caused the maximum annulus pressure to read 205 psi and the maximum injection pressure to read 2047 psi. There was no injection in this well when the high pressures were noted. On March 17 and 18, 2010 BPXA conducted an annual test of the annulus and tubing pressure sensors to verify calibration and shutdown settings. High annulus pressures were produced at the Rosemont sensors in each wellhouse with a hand pump and were not actual well pressures. This accounts for the maximum annulus pressure UIC Manager April 20, 2010 Page 2 exceedances on those days in the Northwest, Southwest, and Southeast wells. There was no injection during when the high pressures were noted. On March 25, 2010 there was a high injection pressure reading for the Northwest well that exceeded the 1400 psi permit limit. The instrumentation shop was testing the alarms by forcing the pressures electronically. The facility was shut down and there was no injection occurring at the time of the test. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including possibility of fine and imprisonment. If you need any clarification or additional information concerning these reports, please contact Alison Cooke, at (907) 564-4838 or Alison.Cooke@bp.com. Sincerely, �1 Arlene Chow North Slope Infrastructure Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2010 Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum MONTH MONTH MONTH January February March 423 409 0 547 544 554 871 765 1,479 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 84 80 92 101 103 142 141 139 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 33 33 0 43 40 42 59 57 152 Injection Volume (Gal) 1. Monthly Total 2. YearlyCumulative 1,280,576 1,038,404 1,243,570 1,280,576 2,318,980 3,562,549 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 36,403 37,086 40,115 96,415 113,774 81,455 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519 - 6612 Permit Number NW Well ADEC 9821 - DB001 EPA Well Permit No. AK - 11004A Name and Official Title Arlene Chow North Slope Infrastructure Manager Signature I� Date Signed 40 a. (—A) EPA Form 7520-8 (2-84) 'The values provided define the non - hazardous range and are not measured values . See Waste Analysis Plan . Values in parentheses ( ) are actual values for permit compliance UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT Year 2010 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum January February March 0 0 0 275 181 171 929 197 2,047 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 0 0 18 0 0 127 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 190 0 17 203 16 27 234 205 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 200,063 0 0 200,063 200,063 200,063 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 6,462 0 0 64,550 0 0 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SE Well ADEC 9821-DB001 EPA Well Permit No. AK -11004A Name and Official Title Arlene Chow North Slope Infrastructure Manager Signature Date Signed EPA Form 7520-8 (2-84) . The values provided define the non -hazardous range and are not measured values. See Waste Analysis plan . The values in parenthesis ( ) are actual values for compliance purposes . UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT YEAR 2009 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum January February March 0 409 0 442 544 579 2,017 765 1,303 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 81 71 78 100 102 141 139 136 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 33 0 39 40 54 84 57 158 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 904,693 982,918 1,235,497 904,693 1,887,610 3,123,107 Temperature (F) 1. Minimum 2. Average 3. Maximum 35 35 35 50 50 50 130 130 130 pH 1. Minimum 2. Average 3. Maximum 2 2 2 7 7 7 12.5 12.5 12.5 Other 1. Monthly Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallons/Da 29,158 35,104 39,855 98,070 112,241 79,758 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-6612 Permit Number SW Well ADEC 9821 - DB001 EPA Well Permit No. AK - 11004A Name and Official Title Arlene Chow North Slope Infrastructure Manager Signature ( Date Signed �t d We) EPA Form 7520-8 (2-84) ` The values provided define the non - hazardous range and are not measured values . See Waste Analysis Plan . Values in parentheses ( ) are actual values for permit compliance . Pad 3 - Injection Composition Summary North Slope Technical Services 01/01/2010 to 03/31/2010 Equipment Services Group By Component Component Barrels Acid 193.54 Ammonium chloride 6.57 Aqueous Solutions 1.00 Arctic Pac 66.80 Boiler Blowdown 1,094.00 cellar box fluids 18.00 cement spacer 37.80 Cement/Contaminate 6,062.77 Chemclear 1.00 class 1 floor sump 13.00 class 1 rinsate 11,769.48 class 1 sump fluids 593.00 class lwell fluids 580.00 class 2 fluids 100.00 class 2 rinsate 11,929.85 Crude Oil 2,223.17 Cuttings 0.37 Diesel 3,144.52 Diesel/Water Gel 1,245.70 Domestic Water 2.97 Drilling Mud 5,399.25 Drum rinsate 78.00 EC9360A Dispersant 1.00 EC9398A Bright water 1.00 f103 6.68 Freeze protect fluid 147.00 Fresh Water 37,002.33 Glycol 92.01 Gravel/Sand 25.00 Hydrotest Fluid (water) 0.22 Line pigging solids 239.83 [3-lMusing S2".MWWWWE.m .Nw2.50 Printed on Saturday, April 03, 2010 Page 1 of 3 Pad 3 - Injection Composition Summary North Slope Technical Services 01/01/2010 to 03/31/2010 Equipment services Group By Component Component Barrels lo66 1.76 Magnesium oxide 18.00 Methanol 2,297.74 NH4CL 19.50 non haz soap 0.26 02 scavenger 8.00 off spec product 1.00 Photo processor fluids 14.00 pigging fluids 80.00 Produced Water 7,917.92 production facility fluids 10.00 Reserve/Flare/Relief Pit Water 4,060.00 Rinsate 798.00 sand 2.20 Scale/Corrosion Inhibitor 1.52 Seawater/Brine/KCI 48,217.60 snow melt 0.40 Snowmelt 465.00 snowmelt/ponded water 290.00 Soap 1.21 Soda ash 10.00 SPILL CLEANUP MATERIAL 720.00 Spill Cleanup Waste 1,051.00 Sump fluids 6,053.00 Turbine washwater 4.00 unused fluids 290.00 Used Oil 0.03 VWR Phenlarsine 1.00 wash waters 129.60 washing machine water 82.00 water 4.20 Gf fod—V Amm 2000-Mm*WFE b-Rov TSD Printed on Saturday, April 03, 2010 Page 2 of 3 Pad 3 - Injection Composition Summary North Slope Technical Services 01/01/2010 to 03/31/2010 Equipment Services Group By Component Component Barrels well bore fluids 964.20 well cellar fluids 117.00 Total Volume: 155,706.00 GannaWwOv A- 2000 -MSN! fFE.�.Av2.5b Printed on Saturday, April 03, 2010 Page 3 of 3 Total Well Volumes 350000 300000 250000 N 200000 M 150000 100000 50000 - - --- ---- - -- ---- 0, ,`O ,`O ,�O ,�o ,�o NQ) ,moo ,�o ,moo NQ1 NQI No ��O ��O 1r�1 ��o ",�T30 AThO AT1O ATO X20 4" o h NN�N��o ��� ������N�RN��o N\3 Days Total Volume Injected - - Limit- - - 0 .y a Maximum Annular Pressure 160 140 --- ---- -- --- 120 - - - - 100 ---- -- - - -- - - 80 60 40 20 \tio \`�o \`Lo \`�o \`�o \`�o \`Lo \`�o \�o \moo ►�\20 \�o \�o \T Days NW S SE i.------ Limit j Maximum Injection Pressure 2500 r111 1500 .y CL 1000 60114 04 - X20 NO Days NW -- SW SE — Limit i •I Maximum Annular Pressure 160 140 - - - - -- -- - -- --- - -- -___ - -- - --- — --- -- 120 - - _ . - - - -- - ----- -- - - - - - - 100 - -- — - - -- --- - - - - -- - - - - -- - -- - --- — - - - -- - - ----- - CL8p - - -- -- - --- ----. -- - --- 60 - ---- - -- -- --- -- - - ---- - — -- - - ---- - -- -- --- 40 ----- -- - -- - - - - --- ------ - --- ----- - - - - -- 20 - -- -- - - — - — — -- --- - ----- - - - - -- --- . -- -- -- - -- 0- �o �o pyo 20 �o Days NW SW SE - Limitj 0 • Maximum Injection Pressure 1600 1400 - - 1200 1000 -- --- --... - ---- -- -- -- - ----- ---------- a800 - -- - - ---- --- - ---- -- ------------ 600 -- - ---- --- --- - ---- - - - - --- - - -- -- - -- - ---- — ----- 400 200 - — 0 No No No No NQ) ,moo ,�O ,�O ��o X20 \�o 1153o o o o ��o ��o Days ---N-� SW SE Limit 40 Total Well Volumes 350000 300000 - - - --- - - -- -- 250000 --- . ----- - --- __ - - --- N 200000 - - - - -- ---- a& L m 150000 - - - - - - - -- 100000 - - -- --- - - 50000 --- ----- 0 \Tp \Tp \D \Tp \Tp \Tp \Tp \2p \Tp \moo \�O \TO ' \�O \ro `Z b 2�`LtiAtip' C ti ti �L (L r6l tido (L��r1 Days Total Volume Injected — Limit •I 0 250 200 150 100 50 Maximum Annular Pressure 0- -, Days — NW i SW ---m S E Limit •� 0 250( 200( 150( .r CL 100( 50( 0 Maximum Injection Pressure 3\ Days 1\�ONO ,\rOO�O ---NW —SW —SE — Limit i 40 0 Total Well Volumes 350000 300000 250000 N 200000 CO 150000 100000 50000 --- -- - ---- - ---- - - - 0 Days Total Volume Injected' -- Limit 0 0 l • • Proposed Schedule for 2010 Mechanical Integrity Testing Class 1 Well (s) MIT Deadline Proposed MIT Flexibility Fluid Movement test date in test Logs Planned after date? MIT? Milne Point By April 6, 2010 Late March/Early Fluid movement logs MPB-50 April 2010 are not required till 1�150 2011. Badami B1-01 By September Late July 2010 Weather Fluid movement logs 15, 2010 permitting are required in 2010 because of the scheduled drilling program and are planned during the summer barge season. Northstar NS 10 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer barge season. Northstar NS32 By August 12, Late July 2010 The Water Flow Logs 2010 will be conducted during the summer barge season. Liberty CRI Well N/A September 2010 All logs required to complete the well will J�\® V be scheduled with the MIT. Pad 3 - NW, SE, By September Late September Yes Borax -RST logs for and SW 26, 2010 for SE / Early October, each well, scheduled and NW wells 2010 with MIT's. and by Caliper logs in ):Z' November 7, summer/fall 2010. 2010 for SW well (Can be 3 months later with Director discretion Grind and Inject By October 25, Late September Yes Shut -In Temperature - GNI-02A, GNI- 2010 for GNI- / Early October, Logs and/or Water 03, and GNI-04 02A, GNI-03 and 2010 Flow Logs planned for Z COC�� GNI-04. summer 2010. Caliper logs in 1 i -k as summer/fall 2010. Alison D. Cooke Environmental Advisor, Air Quality CERTIFIED MAIL # 7008 1830 0001 2703 7263 February 23, 2010 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 I CrBP Exploration (Alaska) Inc. P. 0. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 Direct 907 561 5111 Phone: (907) 564-4838 Email: Alison.Cooke@bp.com Web: www.bp.com t M. Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 Mr. Shawn Stokes Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 RE: Mechanical Integrity Test Notifications Badami Class 1 Iniection Well UIC Permit AK -11001-A, Disposal Infection Order No. 12 General Wastewater Permit No 2005DB001-0010 Northstar Class 1 Iniection Wells, UIC Permit AK -1 1002-A, General Wastewater, Permit No. 2005DB001-0020 Milne Point Iniection Well, UIC Permit AK -1 1005-A, General Wastewater Permit No. 2005DB001-0001 Pad 3 Iniection Wells, UIC Permit AK -1 1004-A, Wastewater Disposal Permit No. 2005DB0001-0021 Grind and Iniect Iniection Wells UIC Permit AK -1 1008-A, Area Injection Order No. 4E -General Wastewater, Permit No. 2005DB00l-0012 Liberty Class 1 Iniection Well, UIC Permit AK -11013-A General Wastewater Permit No. 2005DB001-0025 r Mechanical Integrit t Notification February 23, 2010 Page 2 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) the annual Mechanical Integrity Test (MIT) and fluid movement test that is required every other year at the Badami Class 1 well to meet the permit requirement in UIC Permit AK -11001-A; 2) the MIT and fluid movement tests at the Northstar NS10 and NS32, Class 1 wells to meet the annual permit requirement in UIC Permit AK -11002-A; 3) the MIT and fluid movement test that is required every three years at the Milne Point Class 1 well to meet the permit requirement in UIC Permit AK -11005-A; 4) the MIT and fluid movement tests at the Pad 3 Class 1 wells in the Prudhoe Bay Unit to meet the annual permit requirement in UIC Permit AK 11004-A; 5) the MIT and fluid movement tests at the Grind and Inject Facility, in the Prudhoe Bay Unit to meet the annual permit requirement in UIC Permit AK -11008-A; and 6) the MIT and fluid movement test that is required at the Liberty Class 1 well to meet the permit requirement in UIC Permit AK -11013-A. By this letter BPXA is providing the written notification required by the aforementioned permits. In addition, BPXA staff will be coordinating the timeframes for these MIT and fluid movement tests with Mr. Thor Cutler of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA inspector, so that multiple tests of Class 1 wells can be witnessed in one trip to the North Slope. A summary of the proposed annual testing is presented in the attached table. The fluid movement test procedures that require EPA approval have been or will be sent under separate cover or by e-mail. If you have any questions, please contact me at (907) 564-4838. Sincerely, Alison Cooke Environmental Advisor Attachment cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant slrf111NN11W w Alaska Data & Consulting Services 2526 Gambell Street, Suite 400 Anchorage, AK 99603-2636 ATTN: Seth well NO. 5160 - E- �. ZVQi3 Company: State of Alaska Alaska Oil & Gas Cons Comm ` J Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Job it Log Description Date BL Color CD OWOW-Sw 83SO-00032 RST/WFL 11/07109 1 1 L-223 B58I-00014 USIT Cc10/21/09 1 1 S-216 BSJN-00018 USIT IQ AA 1 10/21/09 1 1 L-222 03SO.00031 USIT 11107/09 1 1 1-2-24 8148-00079 RST / 10/31/09 1 1 1-2-32 8146-00079 RST 10/30109 1 1 • L1-14 AVIIH-00029 RST 10/27/09 1 1 L2 -118A 0148-00077 RST 10/30/09 1 1 D -28B AX13D-00053 MCNL 10102/09 1 1 S-228 BSKS-00008 RST r-1 11127109 1 1 D-24 AWLS -00038 RST 09/27/09 1 1 18-158 AYS4-00107 RST 10/31/09 1 1 04-21 ANHY-00115 RST 10/27/09 1 1 L2 -07A AYO -00047 RST 10/29/09 1 1 OWDW-Sw 83SO-00032 RST 11/07109 1 12-05APSI 40015441 ON MWDILWD EDiT 07/01/07 2 1 06-218 06AKA0016 OH MWD/LWD EDIT 07128108 2 1 U -16A 09AKA0175 OH MWD/LWD EDIT 09/07/09 2 1 L-223 09AKA0081 OH MWO/LWD EDIT10/10109 2 1 L-223 B581-00014 CH EDIT PDC (USIT) 10/21109 1 S-218 BSJN-00018 CH EDIT POC (USIT) Q4 10/21109 1 L-222 133SG-00031 CH EDIT POC (USIT)C1 -r A 10i At'5154f 111107109 1 04-33A 09AKA0075 OH MWD/LWD ED17 09/19/09 2 1 PLEASE ACKNOWLEUGE RECEIPT HY 51UNINU ANU MEIUMNINU UNt COPY tACM IU: SP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503.2838 Schlumberger Alaska Data & Consulting Services 'r etf tppti� 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date BL NO. 5180 83SO-00032 Company: State of Alaska 1 Alaska Oil & Gas Cons Comm L-223 Attn: Christine Mahnken USIT 333 West 7th Ave, Suite 100 1 Anchorage, AK 99501 Color CD OWDW-SW 83SO-00032 RSTNVPL 11/07/09 1 1 L-223 B581 -000i 4 USIT 10121/09 1 1 5-218 85JN-00018 USIT 10/21/09 1 1 L-222 83SO-00031 USIT 11/07/09 1 1 L2-24 8148-00079 RST / 10/31/09 1 1 1-2-32 8148-00078 I RST10/30/09 1 1 L1-14 AVIN-00029 RST 10/27/09 1 1 1.2-18A 8148-00077 RST 10/30/09 1 1 D-288 AXBD-00053 MCNL — jj 10102/09 1 1 S-228 SOK5-00008 RST '" I 10/27/09 1 1 0-24 AWLS -00038 RST 09/27/09 1 1 18-15B AYS4-00107 RST 10/31/09 1 1 04-21 ANHY-00115 RST 10!27109 1 1 L2 -07A AYGO-00047 RST 10/29/09 1 1 OWDW-SW 83SG-00032 RST Q 1 J3 11/07/09 1 12-05APB1 40015441 ON MWD/LWD EDIT — 07/01/07 2 1 06-218 OBAKA0016 OH MWD/LWD EDIT 07/28/08 2 1 O -16A 09AKA0176 ON MWD/LWD EDIT 09/07/09 2 1 L-223 09AKA00SI ON MWDILWO EDIT 10/10/09 2 1 L-223 B5 81-0 001 4 CH EDIT PDC (USIT) 10/21/09 1 S-218 85JN-00018 CH EDIT PDC (USIT) 10/21/09 1 L-222 133SO-00031 CH EDIT PDC (USIT) ARAW 11/07/09 1 04.33A 09AKA0075 OH MWD/LWD EDIT 09/19/09 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: SP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, SuBe 400 Anchorage, AK 99503-2838 LJ Certified Mail # 7008 3230 0000 2489 0640 October 29, 2009 NNEL) hIio v ' f! 20019 BP Exploration (Alaska) Inc. P O. Box 196612 900 East Benson Boulevard Anchorage, AK 99519-6612 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) OCT 3 0 2009 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 NOVO, Vil Gas Con. Commission Re: Demonstration of Mechanical Integrity, Prudhoe Bay Pad 3, Anchorage UI charUIC Class I Permit AK -1 1004-A Q V-'� �)\N - Dear UIC Manager: w ./��� i�1 �1_v�l •- C��� \ This letter is to submit the results of the required annual demonstration of mechaical integrity for the three UIC Class I wells located at Pad 3 in the Prudhoe Bay Unit and operated by BP Exploration (Alaska), Inc (BPXA). The tests are required under Part II, C.3 of EPA UIC Class I permit AK11004-A. The tests were conducted in compliance with the permit requirements and in accordance with approved procedures. EPA representatives Thor Cutler and/or Talib Syed witnessed the annulus pressure tests and the fluid movement logs. The annulus pressure tests, also known as Mechanical Integrity Tests (MITs) were performed in the three wells on September 26, 2009. All three wells passed the MITs. The fluid movement logging requirement was satisfied with borax -RST logs along with shut-in temperature logs to provide additional information. These logs were run by service company Schlumberger in well OWDW-SE September 23, 2009 and in OWDW-NW on September 24 and in OWDW-SW on September 25. There was no indication of fluid movement behind the casing above the approved injection interval in the NW and SE wells, but an anomaly appeared in the SW well log. Shut in temperature passes were run after pumping ceased to provide additional information. The temperature passes did not.confirm the anomalies. The SW well has remained shut in and additional logging is planned to confirm mechanical integrity in the SW well. Detailed information regarding the results of the MITs and the logs are contained in the attachments. They include descriptive and interpretive analyses of the tests and logs and also copies of the borax -RST and temperature logs. I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. BPXA understands that the EPA will notify BPXA of the acceptability of the mechanical integrity demonstration within 13 days of receipt of the results of the mechanical integrity tests (Part II, C.3.c.(4)). Injection may continue during this 13 day review period. If the EPA does not respond within 13 days, we will conclude that the results are acceptable and will continue with injection. UIC Manager • • October 29, 2009 Page 2 If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, IJV/ 7 GSI- el � � Bill E. March Infrastructure Protect Manager Cc: Thor Cutler, EPA Region 10 Talib Syed, EPA Consultant Jim Regg, AOGCC Shawn Stokes, ADEC Mike Bill, BPXA Attachments: Mechanical Integrity Test Results Mechanical Integrity Test Forms OWDW Surveillance Procedures OWDW Northwest Borax PNL Survey Results OWDW Southwest Borax PNL Survey Results OWDW Southeast Borax PNL Survey Results Enclosures: 2 copies each of the following Schlumberger logs: - OWDW-NW Schlumberger RST Sigma Borax Log, Temp/Press/GR/CCURST, 24 - September -2009 - OWDW-SW Schlumberger RST Sigma Borax Log — Temp/Press/GR/CCL/RST, 25 - September -2009 - OWDW-SE Schlumberger RST Sigma Borax Log, Temp/Press/GR/CCL/RST, 23 - September -2009 Mechanical Integrity Test Results Pad 3 OWDW Injection Wells Prudhoe Bay Unit Annulus pressure tests on the Class I Oily Waste Disposal Wells at Pad 3 were performed on September 26, 2009. The tests were performed in accordance with the stipulations of the permit. In each well, the nitrogen cushion was bled off and displaced with diesel. The annulus was then pressured to above 1500 psi and observed for 30 minutes. The results of the tests were as follows: In each well, the pressure decline was less than 10 percent during the test period, with less than 1/3 of the total decline in the second half of the 30 minute period. This shows a stabilizing tendency as specified in EPA Permit AK -1I004 -A, Part II, C 3 b (1). Annulus pressures were observed on a test gauge. During the test period, the tubing pressure was essentially constant in each well. The pressure decline observed may be the result of shrinkage due to cooling of the well fluids during the test. The testing was witnessed by EPA representatives Thor Cutler and/or Talib Syed. AOGCC inspector (Bob Noble) was also on site. I conclude from the successful MIT's that the casing, tubing and packer in the NW, SW and SE wells are in sound mechanical condition. This is consistent with the absence of any indication of tubing or packer leakage during normal injection operations when there is a large pressure differential (>500 psi) between the tubing and the annulus in each of the wells. Michael L. Bill October 29, 2009 Tubing Pressure Annulus Pressure psi 1 st Half 2nd Half Test Pad 3 Well Start / End Start 15 Min 30 Min Decline Decline Result Northwest 460/460 1510 1420 1400 90 20 Passed Southwest 530/530 1505 1390 1370 115 20 Passed Southeast 100/100 1510 1420 1400 90 20 Passed In each well, the pressure decline was less than 10 percent during the test period, with less than 1/3 of the total decline in the second half of the 30 minute period. This shows a stabilizing tendency as specified in EPA Permit AK -1I004 -A, Part II, C 3 b (1). Annulus pressures were observed on a test gauge. During the test period, the tubing pressure was essentially constant in each well. The pressure decline observed may be the result of shrinkage due to cooling of the well fluids during the test. The testing was witnessed by EPA representatives Thor Cutler and/or Talib Syed. AOGCC inspector (Bob Noble) was also on site. I conclude from the successful MIT's that the casing, tubing and packer in the NW, SW and SE wells are in sound mechanical condition. This is consistent with the absence of any indication of tubing or packer leakage during normal injection operations when there is a large pressure differential (>500 psi) between the tubing and the annulus in each of the wells. Michael L. Bill October 29, 2009 • • Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Surveillance Procedures Back round EPA permit AK -1I004 -A effective 12/07/99 requires an annual fluid movement test, Part H C 3 b (2). Notice of the proposed test schedule and the proposed test procedure was sent via email to Thor Cutler, EPA Region 10 on August 26, 2009. The procedure specified a very similar technique that was used in previous tests. The Borax-PNL technique involves comparing pulse neutron log (PNL) passes occurring before and after pumping a solution of borax dissolved in warm water as a tracer. Borax is composed of hydrates of sodium tetraborate. Boron has an inherently high neutron capture cross section. A PNL indicates a significantly higher Sigma value when boron is present, so an overlay of log passes quickly indicates those areas within and adjacent to the wellbore where boron accumulates due to injection of the tracer. This technique is commonly used for cement channel detection in development wells on the North Slope of Alaska. A PNL, Schlumberger's RST (Reservoir Saturation Tool) is utilized for these surveys due to its availability at Prudhoe Bay and because it has been proven capable to detect the presence of boron laden fluids within and external to the wellbore. Borax-PNL Survey Procedure - EPA permit AK- 11004-A requires tracer surveys to "... be run at injection pressures at least equal to the maximum continuous injection pressure observed in the well in the previous 6 months ...". Injection into the OWDW wells is on an as needed basis, often with multiple short injection periods during each day. The average and maximum injection pressures are reported quarterly on EPA Form 7520-8. - Daily average and maximum daily injection pressures did not exceed 684 and 965 psi respectively in that 6 month period. There was no injection in OWDW-SE during the 6 months prior to the tests. Wellhead pressures were 1000 psi or above for each well during the high rate pumping (2.8 to 4 barrels per minute) of borax solution. - The injection rate was reduced to minimum rate during individual log passes to minimize frictional drag on the logging tool due to high fluid velocities and small clearance between the tool (max diameter— 1.72") and the tubing ID (1.995" in 2-3/8" or 2.441" in 2-7/8"). - In each well, the survey procedure involved the following steps: run baseline temperature and RST log pump 100 barrels hot water, high pump rate run RST baseline pass, minimum pump rate pump 30 barrels hot borax -water solution, high pump rate run RST pass, minimum pump rate pump at least 30 barrels hot borax -water solution, high pump rate run RST pass, minimum pump rate pump 15 barrels hot water at low rate to flush wellbore run final RST pass, minimum pump rate Page 1 of 2 • • Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Surveillance Procedures Optional Pump -in Temperature Survey Procedure Considerations To provide additional data if needed, an optional procedure was included in the procedure consisting of a series of three shut in temperature passes following the Borax-PNL survey operations to compare with the baseline temperature pass. The first pass was planned immediately after flushing borax from the well bore with hot water; the second was planned after 1 hour, the third after 2 hours, etc. Shut In temperature survey passes were made in the SW well to provide additional information. Michael L. Bill October 29, 2009 Page 2 of 2 0 • Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Southwest (Pad -3 SW) Background - On 09/07/09, a slick line drift and tag run verified access to the SW well to 2009' MD feet. This is below the top of the perforations and assured sufficient interval was available to perform the survey. - OWDW-SW injected normally during the previous six months. During that period, the average and maximum daily pressures did not exceed 684 and 900 psi respectively. Well head pressures during pumping were at or above 1000 psi. Borax-PNL Survey Results - reference OWDW-SW Schlumberger RST Sigma Borax Log — Temp / Press / GR / CCL / RST, 25 -September -2009. Note: the depths referenced below refer to the Borax -RST log which was run with depths referenced to BGL (below ground level), as in RST logs from previous years. The wellbore schematic included in the log is referenced to RKB (reference Kelly bushing). The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to above 1500' MD. In addition, sigma overlays of selected passes were prepared to compare the log response at various times during the survey. Each sigma overlay contains the following traces: formation gamma ray (API units), casing collar locator, formation sigma (capture units), borehole sigma (capture units). - Two baseline sigma passes were run, one before and after pumping about 100 barrels of hot water. The water baseline pass was used for comparison to subsequent passes. - "RST -Sigma and 40 BBLS Borax Overlay". This overlay shows the change in tool response between the second baseline pass and a pass run after pumping the first stage of borax solution. During this pass borax solution was being pumped at minimum rate to minimize tool drag. The shading on the overlay indicates areas of increased sigma. Below the tubing tail, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the tubing tail, there is a small shift in wellbore sigma (1/4 to %2 chart division) due to the small volume of borax solution surrounding the tool while it is in the tubing (Tubing ID=2.441", RST Tool max OD= 1.72"). There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. In fact, a small decrease of up to 1 chart division was noted in the formation sigma below the tubing tail. This is believed to an artifact of the processing algorithm. Typically, the increase in formation sigma due to the displacement of formation fluids adjacent to the wellbore with borax solution is 2- 1/2 to 6 chart divisions or 5 to 12 capture units. - "RST -Sigma Baseline and 80 BBL Borax Overlay". An additional 40 barrels of boron laden fluid was pumped prior to running this pass. There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. - "RST -Sigma Baseline and 120 BBL Borax Overlay". An additional 40 barrels of boron laden fluid was pumped prior to running this pass. There is no significant increase in formation sigma due to an accumulation of borax solution exterior to the casing. - "RST -Sigma Baseline and 15 BBL KCL flush Overlay". This overlay shows the tool response after flushing boron solution from the wellbore with water at low pump rates. The wellbore sigma returned to baseline levels. There are two areas of anomalous readings with potentially significant high formation sigma at 1782-1789' and 1798-1805' MD. There are no areas of a significant increase in formation sigma above or below these intervals. Page 1 of 2 0 • Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Southwest (Pad -3 SW) Baseline Temperature Survey - shown on log trace "Baseline Temp Pass Up at @ 30 FPM". Reference OWDW-SW Schlumberger RST Sigma Borax Log — Temp / Press / GR / CCL / RST, 25 -September -2009. - The baseline temperature pass was run to provide a basis of comparison for subsequent passes if needed. The baseline log is similar in character to past baseline temperature surveys. These logs show significant permafrost warming due to vertical and radial heat transfer from injection operations from the perforations up to about 1650' MD. - Shut In temperature passes were run to provide additional information on the formation sigma anomalies at 1782-1789' and 1798-1805' MD. Temperature passes were run immediately after pumping ceased then beginning at 1 hour intervals for 5 for a total of 6 temperature passes. - An overlay the post pumping shut in temperature passes with the baseline gave no indication of upward fluid movement and did not confirm the anomalous formation sigma readings. The character of each pass was very similar and the rate of cooling back toward the baseline was consistent between passes. - A repeat Borax RST log with Waterflow log stops will be run to confirm there is no channeling adjacent to the wellbore. Overall Conclusions 1. Anomalous formation sigma readings were observed in two small intervals 175-200 feet above the perforations on the final RST pass after pumping a large amount of borax solution and then flushing the wellbore with water. All previous sigma passes overlayed the baseline across this interval. Schlumberger log analysts reviewed the log quality data and did not discover any explanation for the anomalous readings. 2. None of the sigma overlays showed no indication of channeling from the perforations upward to the anomalous intervals. 3. Post pumping shut in temperature passes showed no evidence of channeling adjacent to the wellbore and did not confirm the anomalous readings. 4. A repeat of the Borax -RST log along with a Waterflow log could confirm or eliminate the anomalous readings. 5. Most, if not all, of the fluid pumped during the test was confined within or very near the perforated interval. 6. In general, these results (other than the anomalous intervals) are consistent with prior surveillance indicating injection probably takes place through a horizontal fracture within or near the perforations. There is a large area of reservoir permeability damage near the wellbore from past injection. (Reference: Section 6, UIC Class I Permit Application for the Pad 3 Injection Facility, submitted February, 18, 1999). 7. The annulus pressure test performed on 09/26/09 indicates the tubing and casing are hydraulically sound. Michael L. Bill 10/29/09 Page 2 of 2 0 0 United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutier.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-SW AK -1I004 -A 1002380 Injector MIT Type I Test Type Test Date Class I T X IA I Std. Annular Pressure Test (S APT) 9/26/2009 Req'd Test Fluid Type(s) used to tes PackeTwpth (ft, Test Interval / Comments Presssure (psi) RESULT PIF PASS TUBING 530 530 530 530 1,500 Diesel 1,902' 1 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T E S T 1 START TIME: 00:00 am/pm PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PIF PASS TUBING 530 530 530 530 INNER ANNULUS 0 1505 1390 1370 OUTER ANNULUS COMMENTS: T E S T 2 START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS OUTER ANNULUS COMMENTS: T E S T 3 START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS OUTER ANNULUS COMMENTS: MISC COMMENTS: Last test MITIA -10/8/08 (witness T.S drf.Cutler), Borax-PNUtemp survey - 10/5/06. Originally drilled in the 1970s to test the thaw characteristics of permafrost. Last ran MITIA to 1600 psig on 10/8/08. Loss was 80 psi after 15 min and 100 psi after 30 min (less than 10 % allowable) NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). LTJ u o-- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Talib Syed, P.E./ Thor Cutler Bob Noble Anna Dube MEMORANDUM 0 Ah TO: Jim Regg It 2'7��' P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, October 23, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC O WD W -S W PRUDHOE BAY UNIT OWDW-SW Src: Inspector NON_C(1NF1i1FNT1A T Reviewed By: P. 1. Supry �!-- r,. Well Name: PRUDHOE BAY UNIT OWDW-SVJ Insp Num: mitRCN091023093735 Rel Insp Num: API Well Number: 50-029-21817-00-00117 Permit Number: 100-238-0 Inspector Name: Bob Noble Inspection Date: 9/26/2009 Packer Well ° sW (Type Inj.� N D TTV -- Depth Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. 1902 - j IA 0 150 1390 1370 — +- P.T.D 1o023s0 iTypeTest SPT Test psi -- i-- lsos OA 1—�_ --- - ------ - Interval OTHER P/F P - --- _ Tubing 530 r 530 530 530 Notes: One year test cycle, EPA witnessed Friday, October 23, 2009 Page 1 of 1 E • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / OW DW 09/26/09 Anna Dube Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well OWDW-NW Type —Injl N TVD 1900 Tubing 460 460 460 4601 Interval O P.T.D.1 1002400 1 Type test I P Test psi 1500 Casing 0 1510 14201 1400 P/F P Notes: MIT -IA for annual regulatory compliance. OA Witnessed by EPA representatives Thor Cutler and Talib Syed. Well OWDW-SE Type Inj. N I TVD 1 1885 Tubingl 100 100 100 100 Interval O P.T.D.1 1002390 1 Type test I P I Test psi 1 1500 Casingl 40 1510 14201 1400 P/F I P Notes: MIT -IA for annual regulatory compliance. OA Witnessed by EPA representatives Thor Cutler and Talib Syed. WeIIJOWDW-SW1 Type Inj. I N I TVD 1 1902 Tubingl 530 530 530 530 Interval O P.T.D.1 1002380 1 Type test I P I Test psi 1 1500 Casingl 1505 13901 1370 P/F I P Notes: MIT -IA for annual regulatory compliance. OA Witnessed by EPA representatives Thor Cutler and Talib Syed. Well I Type Inj. I I TVD I Tubingi I Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: OA Well I Type Inj. TVD Tubing Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 11/27/07 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test A 11t) 1 (01 �. INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover c#R O = Other (describe in notes) t U MIT PBU OWDW-NW OWDW-SE OWDW-SW 09-26-09 (2).xls United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility I Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-SW AK -1I004 -A 1002380 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 9/26/2009 Req'd Test Presssure (psi) Fluid Type(s) used to test Packer Depth (ft, TVD) Test Interval /Comments 1,500 Diesel 1,902' one Y Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T E S T START TIME: 00:00 am/pm PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PIF PASS TUBING 530 530 530 530 INNER ANNULUS 0 1505 1390 1370 OUTER ANNULUS — — — — 1 COMMENTS: T E S T START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS OUTER ANNULUS 2 COMMENTS: T E S T START TIME: PRE MIT RECORDED PRESSURES (PSI) IN]TIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS OUTER ANNULUS 3 COMMENTS: ISC COMMENTS: Last test MMA -1010!08 (wlrr8ss T.Syed/r.Cud"), Borax-PNUtemp survey - 10!5/08. Originally driNed in the 1970s to test the 8raw dwactenstics of permafrost. Last ran MITIA to 1600 psg on 10/8/08. Loss was 80 psi after 15 mn and 100 psi after 30 min (less than 10 % al wmWe) NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 5001. of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). 0 IBJ -- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Talib S rimed, P.E./ Thor Cutter Bob Noble Anna Dube schimbeppP Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well %fid 200"S Job # Log Description Date BL NO Coy L} BP Exploration (Alaska) Inc. l Petrotechnical Data Center LR2-1 900 E. Benson Blvd. mar UNITED• TES ENVIRONMENTAL PROTECTION AGCY REGION 10EEi `' ` moi; y� 1200 Sixth Avenue, Suite 900 �� r. og Seattle, Washington 98101-3140 .i 2009 1jF�r�[ PgO�G� v Y. — �:. Reply To: OCE -127 SEP 3 i Iyv�la CERTIFIED MAIL - RETURN RECEIPT REQUESTED Ms. Janice Vosika Greater Prudhoe Bay Field Manager m� BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 Re: Issuance of Underground Injection Control (UIC) Permit No. AK1I004-B Prudhoe Bay Pad -3 Disposal Facility, North Slope, Alaska Dear Ms. Vosika: The U. S. Environmental Protection Agency, Region 10, (EPA) is issuing an Underground Injection Control permit for BP Exploration (Alaska) Inc. (BPXA), Prudhoe Bay Pad -3 Disposal Facility (Pad -3), North Slope, Alaska. The enclosed document authorizes the facility to inject non -hazardous industrial waste utilizing up to three (3) Class I injection wells at the Pad -3 into the Sagavanirktok formation at approximately 1978-2093 feet measured depth below ground level. EPA received no requests for a hearing and no comments on the draft permit during the public comment period. This letter constitutes service of notice under 40 C.F.R. 124.19(a). The permit will become effective on the date indicated in the permit unless the Environmental Appeals Board receives a timely appeal meeting the requirements of 40 C.F.R. 124.19. Information about the administrative appeal process may be obtained on-line at epa.gov/eab or by contacting the Clerk of the Environmental Appeals Board at (202) 233-0122. Sincerely, Enclosures ski, Director ance and Enforcement cc w/enc: Shawn Stokes, ADEC Division of Water/Wastewater Discharge Permits Dan Seamount, Commissioner, AOGCC , 0c) —_-*"�, oval �� - PrMted on RscycMtl Paper V schlftever Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth OfU-4 a AI r f `)nr),, NO. 5020 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 12/29/08 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 Alaska Data & Consulting Services 900 E. Benson Blvd. 2525 Gambell Street, Suite 400 Anchorage, Alaska 99508 Anchorage, AK 99503-2838 Date Delivered: ATTN: Beth Received by: C� • 11/24/08 Well Job # Log Description Date BL Color CD 02-25A 1 12066545 JMCNL _ f 08/23/08 Schlimbegep 1 OWDW-NW 12096915 IRST o - 10/05/08 1 1 N0.4960 11975798 RST 10/04/08 Q' 1 Alaska Data & Consulting Services 12096916p'rrr yi;x ". '� Jfr_ U Company: State of Alaska 2525 Gambell Street, Suite 400 t� v Irl �/ ) Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 lJ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 P1 ►VA'j' ,/ Anchorage, AK 99501 11/24/08 Well Job # Log Description Date BL Color CD 02-25A 1 12066545 JMCNL _ f 08/23/08 1 1 OWDW-NW 12096915 IRST o - 10/05/08 1 1 OWDW-SE 11975798 RST 10/04/08 1 1 OWDW-SW 12096916p'rrr yi;x ". '� Jfr_ 10/05/08 1 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. Anchorage, Alaska 99508 Date Delivered: s Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2 38 ATTN: Beth Received by: r: • MIT Forms for EPA Compliance: Northstar, Badami, Pad 3, GNI Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer[NSUADWWellintegrityEngineer@BP.com] Sent: Friday, October 17, 2008 9:45 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; Younger, Robert O; Bill, Michael L (Natchiq) Subject: MIT Forms for EPA Compliance: Northstar, Badami, Pad 3, GNI Attachments: MIT ACT NS10 10-11-08.xls; MIT ACT NS32 10-11-08.xls; MIT BAD B1-01 10-09-08.xis; MIT PBU GNI-02A, 03,04 10-07-08.xls; MIT PBU OWDW-NW, SE, SW 10-08-08.xis Jim, Tom and Bob, Please see the attached MIT forms for the following wells for annual EPA compliance testing: NS10 (PTD #2001820): MIT -IA witnessed by Thor Cutler. NS32 (PTD #2031580): MIT -IA witnessed by Thor Cutler. B1-01 (PTD #1971570): MIT -IA witnessed by Thor Cutler and Talib Syed. GNI-02A (PTD #2061190): MIT -IA witnessed by Thor Cutler and Talib Syed. GNI-03 (PTD #1971890): MIT -IA witnessed by Thor Cutler and Talib Syed. GNI-04 (PTD #2071170): MIT -IA witnessed by Thor Cutler and Talib Syed. OWDW-NW (PTD #1002400): MIT -IA witnessed by Thor Cutler and Talib Syed. OWDW-SE (PTD #1002390): MIT -IA witnessed by Thor Cutler and Talib Syed. ,)eGVDW-SW (PTD #1002380): MIT -IA witnessed by Thor Cutler and Talib Syed. <<MIT ACT NS10 10-11-08.xls>> <<MIT ACT NS32 10-11-08.xls>> <<MIT BAD B1-01 10-09-08.xls>> <<MIT PBU GNI-02A, 03,04 10-07-08.xls>> <<MIT PBU OWDW-NW, SE, SW 10-08-08.xls>> Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/20/2008 ktF.Lx O'v' 2 200? I/ 0 STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / Pad 3 DATE: 10/08/08 OPERATOR REP: Andrea Hughes 1 AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. WelIJOWDW-NWJ T pe Inj. N TVD 1 1900 Tubingl 4501 450 450 450 Interval O P.T.D.1 1002400 1 T pe test I P Test psi I 1500 Casingi 201 16301 15101 1490 P/F I P Notes: MIT -IA for annual regulatory compliance. (1st test) OA n/a I n/a I n/a I n/a Witnessed b or Cutler and Talib Syed. WellJOWDW-NW1 V = Required by Variance T pe Inj. I N I TVD 1 19001 Tubingl 4201 4201 4201 4201 Interval O P.T.D.1 1002400 1 T pe test I P I Test psi 1 15001 Casingi 14901 16101 15901 1590 P/FJ P Notes: MIT -IA for annual regulatory compliance. (2nd test) I A n/a I n/a I n/a I n/a Witnessed by Thor Cutler and Talib Syed. Well OWDW-SE Type Inj. I N I TVD 1 18851 Tubingl 101 101 101 101 Interval O 1002390 1 Type test I P I Test psi 1 15001 Casingl 1,5001 1,6101 1,6001 1,600 P/FJ P —P.T.D.1 MIT -IA for annual regulatory compliance. I OA n/a I n/a I n/a I n/a Witnessed by Thor Cutler and Talib S ed. WellJOWDW-SWII TVD 902 Tubing 650 50 650 650 Interval O P.T.D. 1002380 Type test P Test psi 1500 Casing 101 4,60011,5201 1,500 P/F I P Notes: MIT -IA for annual regulatory compliance. OA n/a n/a I n/a I n/a Witnessed by Thor Cutler and Talib Syed. Well I Type Inj. I I TVD I Tubingl I I I I Interval P.T.D. Type test Test psi Casing P/F Notes: I OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU OWDW-NW, SE, SW 10-08-08.xis schlumbepoep Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall 1nh If NO. 4509 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Endicott 11/21/07 Z-10 11676974 GLS + / .-- 11/11/07 1 06-16 11686797 PPROF & RST "' ""s 11/15/07 1 MPL-33 11661179 MEM INJECTION PROFILE 11/13/07 1 MPF -25 11846827 USIT p '/ : - } ' ; 11/10/07 1 GNI-04 11846828 U 11/11/07 1 OWDW-SW 11626128 RST q �'1 ._w t, a '1 ;_,. 10/10/07 1 1 3-35/L-36 11630502 RST � ���i..�; 09/09/07 1 1 15-268 11661165 MCNL r>A .a'.. ��'�ti 08/24/07 1 1 05-36A 10928638 MCNL �!` ,� _ Ci`� I"` t ?� f �� 06/11/05 1 1 07-16A 11216211 MCNL� 7' " "� ; "• ` • i = f _ { 08/27/06 1 1 2-2813/0-19 11638650 RST )��' - �1 �✓ �" -_ v 07/05/07 1 1 07-02A 11649983 MCNL ! -- O't;"",{'' 08/07/07 1 1 N-27 40015763 OH MWD/LWD EDIT 09/11/07 2 1 Gn.aC I1vr♦nvvvCGUWC nCNCir 1 o r 01"1v11Y17 AIYu RC I UMNINU UN �,+.UY3--;Ak H I U: BP Exploration (Alaska) Inc. "t� Petrotechnical Data Center LR2-1 k 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: a+ 9" t ,"s. t.,41� f ?� S,fivl Ea. � I.ri li919 .vaa .raft Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by I ✓, P • • ` 10/30/07 SchlumWepgo NO. 4349 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400t 1n� 7 Alaska Oil & Gas Cons Comm �S Anchorage, AK 99503-2838 b�F.E)N0 V 2 12"0- Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt., Pt. Mac Wan Jnh it t_nn Decrrintion Data RL Colnr CD 1-2-11 11686750 RST — 05& • _ ..--• .- - 05/24/07 1 3-41/K-39 11813054 RST = - 06109/07 1 1 05-22A 11285946 MCNL A 10119106 1 1 P2-22 11649964 MCNL 7t S 04125107 1 1 OWDW-SW 11211392 RST IS-(o�j 04120106 1 1 W-213 40015198 OH MWD/LWD EDIT tt05/29/07 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY lz GH TO; BP Exploration (Alaska) Inc. ,1 � Z Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 I Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-7"11 ATTN: Beth Received by: • • Sc11lumbepp Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh It lau Deo 2 20� I — n .... in}inn NO. 4498 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Pt. Mac. Milne Pt. 11/15/07 MPS -37 11594513 OH LDWG EDIT06/26/07 6 2 1 J -25A 11767130 MCNL 10- 1 06/18/07 1 1 OWDW-SW 11483588 RST J -S(` p0b - 11117/06 1 1 OWDW-NW 11626127 RST 10/09/07 1 1 OWDW-SE 11225967 RST Gtoo 04/19/06 1 1 M -12A 11216184 MCNL - ( 04/04/07 1 1 P1-09 11773114 IRST I L 04!24!07 1 1 OWDW-SE 11855823 JRSTU L, I pt_) _ 10/28/07 1 1 • .. .�.- r.a-..r_u- r o .� vnu v nna.r nc r uniVarv, vr�c Lvr r GNI,A 1 V. BP Exploration (Alaska) Inc. ` Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 1 01 Date Delivered: ,`,E A Desi LiiP i �_� C:otari °;e9�4719Yi{"� zE��li 11j Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received byj2,f • 0 11/05/07 schlumbepoep N0.4360 Alaska Data & Consulting Services Company: State of Alaska 2626 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 8 N NOV 2 12007 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Niakuk, Milne Pt., Pt. Mac, Prince C VUnll Jnh it 1 nn Ilacrrinfinn rlato RI rninr rt) 5-400A 11855508 USIT (REVISED) C 09/18107 1 C-30 11695080 LDL 1 10/16/07 1 Z -22B 11594525 SBHP SURVEY — 10/06/07 1 14-31 11890316 LDL 10/18/07 1 NK -22A 11855822 DRIFT TD/LDL A0 ( —afA 10/25/07 1 MPG -07 NIA CORRELATIONIDDL 09/08107 1 MPG -07 11628799 MEM INJ PROFILE C 10/20/07 1 MPF -10 11767140 MEM INJ PROFILE -S — 09/15/07 1 MPS -05 11745237 MEM PPROF SUPPLEMENT LOG 10/09/07 1 P2 -19A 11649963 MCNL 04/22/07 1 1 OWDW-SW 11221548 RST1,J 03/05/06 1 1 W -17A 11588701 MCNL 12/26/06 1 1 14-30A 11485775 MCNL 6 (p0 11/22/06 1 1 L-51 40013624 OH MWD/LWD EDIT 06126106 2 1 YLtAbh AGKNUWLtUGt Kt:UMV 1 bT WUNINU ANU Kt 1 UKNINU UNt GUYT tAUM IU: 17 BP Exploration (Alaska) Inc. 1-45 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /Y Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: -L Ac--/ • • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to'. Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / Pad 3 10/12/07 Andrea Hughes '2 ((-11cl JOG) Jb TYPE INJ Codes TYPE TEST Codes Packer Depth ` Pretest Initial 15 Min. 30 Min. 4 = Four Year Cycle I = Industrial Wastewater Well I OWDW-Na Type Inj. N I TVD 1 1900 Tubing 5001 500 ,.5001 5001 Interval O P.T.D.1 1002400 1 Type test P L/I Test psi 1500 Casing 0 1600 1570 1560 P!F P Notes: EPA witnessed MIT -IA for annual regulatory compliance. OA n/a I n/a n/a n/a WeIIJOWDW-SEJ Type Inj. N TVD ✓1885 Tubing 01 '01 01 01 Interval O P.T.D. 1002390 Type test P Test psi /1500 Casing 150 1600 15701 15601...P/F P Notes: EPA witnessed MIT -IA for annual regulatory compliance. I OA n/a I n/a n/a n/a WeII1OWDW-SWJ Type lnj. 1 19021 Tubingl 5001 5001 500 5001 Interval O P.T.D. 1 1002380 J Type test I P I Test psi 1500 Casing 0 1600 _I 570 1560 P/F P Notes: EPA witnessed MIT -IA for annual regulatory compliance. I OA n/a n/a n/a ri Well Type Inj. I TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: I OA Weill Type Inj. TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: I OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) 5CM1JF.Q NOV 1 5 2007 MIT Report Form BFL 9/1/05 2007-1012_MIT_PBU_OWDW-SE.xls • STATE OF ALASKA 0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 2 0 2006 REPORT OF SUNDRY WELL OPERATftN8 & Gas Cons. Comin�ssion 1. Operations Performed: rurcTfuragEr- AbandonEl Repair Well❑X Plug Perforations❑ Stimulate ❑ Other[] Alter Casing[] Pull Tubing❑X Perforate New Poo[C] Waiver❑ Time Extension[] Change Approved Program[] Operation Shutdown[] Perforate ❑ Re-enter Suspended Well[] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ❑ Exploratory[] 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic❑ Service❑X 50-029-21817-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.50 OWDW-SW 8. Property Designation: 10. Field/Pool(s): ADL -028311 Prudhoe Bay Field 11. Present Well Condition Summary: Total Depth measured 2250 feet true vertical 2250.0 feet Plugs (measured) Tagged fill @ 2082 (11/17/2006) Effective Depth measured 2134 feet Junk (measured) None true vertical 2134.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 13-3/8" 72# N-80 28 - 100 28.0 - 100.0 4930 2670 SURFACE 2188 5-1/2"..17# L-80 27 - 2215 27.0 - 2215.0 7740 6280 yp t , r b Perforation depth: Measured depth: 1980-2005 True vertical depth: 1980-2005 Tubing ( size, grade, and measured depth): 2-718" 6.5# L-80 @ 24 - 1941 Packers & SSSV (type & measured depth): 5-1/2" Baker F-1 Packer @ 1902 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RWO completed --- cut & replaced part of TBG with 2-7/8" L-80 TBG. 13 Representative Daily Average Production or Iniection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: --- --- --- --- Subsequent to operation: --- --- --- --- --- 14. Attachments: 15. Well Class after proposed work: Exploratory❑ Development[] Service❑X Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ X oil[-] Gas[] WAG ❑ GINJ❑ WINJ❑ WDSPL❑X Prepared by DeWayne R. Schnorr (907) 564-5174. 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1 Contact DeWayne R. Schnorr 305-398 Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature Phone 564-5174 Date 11/20/06 Form 10-404 Revised 4/2004 OIRIGINAL TREE= 2-1/16" FMC WELLHEAD = FMC ACTUATOR = Note: Refer to Production DB for historical perf data KB. ELEV = 56.5' BF. R EV = 32' KOP= 0 Max Angle = 0 Datum MD = 10/19/06 Datum TVD = PJC OWDW-SW DRAFT 11 I I 11 13-3/8" CSG, 72#, N-80, ID = 12.347" Minimum ID = 2.205" @ 1928' 2-7/8" HES XN NIPPLE 1 2-7/8" TBG, 6.5#, L-80, EUE, .0058 bpf, ID =2.441" 1-1 1 PERFORATION SUMMARY REF LOG: DIL ON 06/25/73 ANGLE AT TOP PERF: 0 @ 1980' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 1980-2005 O 10/19/06 PBTD1—{ 2134' 5-1/2" CSG, 17#, L-80, ID = 4.892" 2215' TD 2250' 2-7/8" HES X NIP, ID = 2.313" 900 112-7/8" BKR GBH -22 SEAL LOCATING SUB & ASSEMBLY, ID = 2.370" 1902 ri 5-1/2" X 2-7/8" BKR F-1 PKR, ID = 3.00" 1928 1—{ 2-7/8" HES XN NIP, ID = 2.205" 1941 1--12-7/8" WLEG, ID = 2.441" 2070' 1-I TOP OF FILL (11 /07 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 11/16/06 JCM/PAG RMV SLUGGITS / PULL PLUG 01/01/85 RWO 11/12/06 D16 RWO 05/31/06 DTM WELLHEAD CORRECTION 10/19/06 RDB/PAG SANDBACK/CMT CAP 11/14/06 ?/ PJC JDRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: OWDW-SW PERMIT No: 00-238 API No: 50-029-21817-00 SEC 11, T1 ON, R14E, 1064 FEL, 668 FNL BP Exploration (Alaska) 0 OWDW-SW DESCRIPTION OF WORK COMPLETED EVENT SUMMARY AWGRS 09/11/2006 T/IA/OA = SI/15/OA (Pre rig Inpsection ) PPPOT-T =Passed Bled tubing hanger void off to 0 psi. Torqued lockdown screws to 350 ft/lbs. Rigged up test equipment and pressured up to 2,000 psi. for 30 mins. - Passed AWGRS 09/17/2006 ***WELL S/I ON ARRIVAL*'k" BRUSH & FLUSH W/ BRUSH & 1.70" G -RING OUT TT TO 1930' SLM...DRIFTED W/ 1.75 CENT & TEL, TAG TD @ 1996' ELMD (btm pert @ 2005', 9' of fill). RDMO 'WELL LEFT S/I*** AWGRS 09/17/2006 T/1=400/0 Assist Slickline/ MIT IA @ 1750 psi PASSED.(Shut In)(Pre RWO) Pumped 16 bbls 180*f Diesel into TBG assisting SSL w/ Brush and Flush. IA pressured up w/2.7 bbls of 55* Diesel pumped. 1 st test 1 st 15 min lost 180 fail 2nd test 1 st 15 min lost 70 psi 2nd 15 min lost 30 psi for a total of 100 psi in 30 min bleed IA psi off Final Whp's=320/0 AWGRS 10/03/2006 T/I/O = 600/1750/35 Attempted to test packoff on 13 5/8 2000# bottom flange. Due to severe corrosion on test port fitting, was unable to get cap off and test flange. Will need to bleed OA to 0 psi in order to change test port and test flange. AWGRS 10/05/2006 T/1/0=500/0/30. Temp=Sl. Bleed OA to 0 psi (pre -rig) ETA 10/28. Bled OA from 30 psi to 0 psi in 20 min. Bled FL from 200 psi to 0 psi in 30 min, (Operator request). Final WHP's 500/0/30. AWGRS 10/06/2006 T/IA/OA = 275/Vac/0 (Pre -Rig Inspection) PPPOT-IC = Passed IA bled down to 0 psi. No lockdowns on inner casing packoff, rigged up test equipment and pressured up to 2,000 psi. for 30 mins. -Passed. AWGRS 10/12/2006 CTU #5 ***Pipe Swap to 1 1/2" ***Continue WSR on 10/13/2006*** AWGRS 10/13/2006 CTU #5 ***Convection of CTU & BOPE to 1 1/2" CT*** AWGRS 10/14/2006 CTU #5 ***Standby*** AWGRS 10/15/2006 CTU #5 ***Sand Plug/Cement Plug *** MIRU, BOPE test, MU BHA #1: 1.5" BDN. Bullhead 10 bbls of 60:40 methanol into wellbore. RIH and tag at 1989' ctm. Corrected to slickline depth of 1996'. POOH pumping McOH for CT displacement. Bullhead 270 bbls of 140 deg 1 % KCI . Bullhead 600# 20/40 river sand and displace to 1 bbl from perfs. Allow sand to fall for 2 hours. Attempted to pressure up on plug unsuccessfully. RIH and tagged sand plug at 1992' (corrected). *** Job in progress *** AWGRS 10/15/2006 CTU #5 ***Sand Plug/Cement Plug *** MIRU, BOPE test, MU BHA #1: 1.5" BDN. Bullhead 10 bbls of 60:40 methanol into wellbore. RIH and tag at 1989' ctm. POOH pumping McOH for CT displacement. Bullhead 270 bbls of 140 deg 1 % KCI . Bullhead 600# 20/40 river sand and displace to 1 bbl from perfs. Allow sand to fall for 2 hours. Attempted to pressure up on plug unsuccessfully. RIH and tagged at 1991' POOH Bullhead 900#(1.5x required vol) 20/40 river sand, displace sand to 32' above top pert. Wait 3 hours. Attempted to pressure up, ramped a few times to get to plug up perfs. RIH and tagged at 1992' POOH ***Continue WSR on 10/16/2006*** Page 1 OWDW-SW DESCRIPTION OF WORK COMPLETED AWGRS 10/16/2006 CTU #5 ***Continue WSR from 10/15/2006*** Bullhead 1000# of 20/40 river sand, 2500# total @ this point in the job, wait 3 hrs, tag @ 1992' injection pressure raised to 750psi @ 0.23bpm up from initial injection pressure of 505 psi @ .23 bpm. Bullhead 800# of 20/40 river sand, 3300# running total, wait 3 hrs, tag @ 1992', injection pressure at 460 psi @ 0.25 bpm. Bullhead 1400 # of 20/40 river sand (4700# running total). *** Job in progress *** AWGRS 10/16/2006 CTU #5 ***Continue WSR from 10/15/2006*** Bullhead 1000# of 20/40 river sand, 2500# total @ this point in the job, wait 3 hrs, tag @ 1992' injection pressure raised to 750psi @ 0.23bpm up from initial injection pressure of 505 psi @ .23 bpm. Bullhead 800# of 20/40 river sand, 3300# running total, wait 3 hrs, tag @ 1992', injection pressure at 460 psi @ 0.25 bpm. Bullhead 1400 # of 20/40 river sand (4700# running total). Tag @ 1980', PUH and prep to pump additional sand.***Job continued on 10/17/2006 WSR*** AWGRS 10/17/2006 CTU #5***Continue WSR from 10-17-06***Circulate in 400# 20/40 and 100 mesh sand(5100# running total sand) . Tag 1974'. Circulate well over to XS KCL. Prep to pump cement. Pumped 2 bbls of fresh water ahead. Pump 2 bbl of 17 ppg Class G using 2 foam pigs. Displaced with 2 bbls fresh water behind cement. Laid in cement from 1964' to 1900' at minimum rate. Contaminated with 5 bbls of 1.5 ppb Biozan to 1923'. Dropped 5/8" ball in middle of Biozan stage. Chased OOH maintaining 200 psi overbalance on formation. Washed tree and BOPs while maintaining 770 psi WHP. RIH pumping 1% XS KCI and washed from 1800' to 1923' with 3 passes. Continued circulating warm 1 % KCI from 1923' for 450+ bbls. *** Job in progress *** AWGRS 10/17/2006 CTU #5***Continue WSR from 10-17-06***Circulate in 400# 20/40 and 100 mesh sand(5100# running total sand) . Tag 1974'. Circulate well over to XS KCL. Prep to pump cement. Pumped 2 bbls of fresh water ahead. Pump 2 bbl of 17 ppg Class G using 2 foam pigs. Displaced with 2 bbls fresh water behind cement. Laid in cement from 1964' to 1900' at minimum rate. Contaminated with 5 bbls of 1.5 ppb Biozan to 1923'. Dropped 5/8" ball in middle of Biozan stage. Chased OOH maintaining 200 psi overbalance on formation. Washed tree and BOPs while maintaining 770 psi WHP. RIH pumping I% XS KCI and washed from 1800' to 1923' with 3 passes. Continued circulating warm 1 % KCI from 1923' for 617 bbls. ***Job continued on 10-18-06 WSR*** AWGRS 10/18/2006 ***Job continued from 10-17-06 WSR ***Continue circulating warm 1% KCL down well. Circulate 60/40 down coil and well. POOH. Standby for lab results on cement. MU BHA w/ 1.75" JSN. PT wellbore to 1750 psi. Passed. RIH and tag cement top at 1929.5' up wt. POOH. RDMO. *** Job complete *** AWGRS 10/26/2006 T/I/O = 0/0 -Assist E -Line - Pumped 2 bbls neat meth followed by 60 bbls 120* 1% KCL down IA taking returns up TBG to open top tank. Freeze protect hardline from tree to tank w/3 bbls neat meth. FWP's = 0/60 AWGRS 10/26/2006 SHOT TUBING PUNCHER FROM 1858'- 1860'. SHOT STRING SHOT FROM 1870' - 1882'. JOB INCOMPLETE. ***CONTINUED ON 27 -OCT -2006*** AWGRS 10/27/2006 ***CONTINUED FROM 10/26/06*** CHEMICAL CUT TUBING AT 1880' USING 1-11/16" CHEM CUTTER. POSITIVE INDICATION OF CUT SEEN ON SURFACE. JOB COMPLETE. WELL LEFT SHUT IN AND TURNED OVER TO DSO. Page 2 0 0 OWDW-SW DESCRIPTION OF WORK COMPLETED AWGRS 10/27/2006 *** Job continued from 10/26/06 WSR *** T/I/O = 0/0/30 (circ string) - Post Circ out freeze protect (RWO prep) - Pumped 4.5 bbls 120* diesel down 1 1/4" circulating string. Pumped 2 bbls neat meth followed by 60 bbls 115* diesel down TBG taking returns up IA to open top tank. FWP's =0/0/0 DIMS 10/31/2006 Rig Down, Move Off 07-19A, Move and Spot on OWDW-SW, Displace Well to 13.9 ppg Mud DIMS 11/01/2006 Assemble and Install 7 1/16" BOP Stack, Test BOPE, DIMS 11/02/2006 Test 7 1/16" BOPE, R/U and L/D 1 1/4" Tbg, C/O Rams, R/U and Pull 2 3/8" Tbg to Rig Floor. DIMS 11/03/2006 L/D 2 3/8" Tbg, UD Hanger, Set and Test RBP, N/D 7 1/16" BOP Stack, N/D Tbg Spool DIMS 11/04/2006 N/U Tbg Spool, N/U and Test BOPE, M/U BHA #1, RIH, Engage Seal Assembly DIMS 11/05/2006 POOH, L/D Seal Assembly, M/U Pkr Mill, RIH, Mill Pkr, POOH DIMS 11/06/2006 RIH, POOH with Seal Assembly, RIH with Csg Scraper, Circulate Sweep, POOH, RIH, Drill Cmt. DIMS 11/07/2006 Continue to Drill Cement to 1,989', Wash Sand 2,070' RKB , Pump Sweep Circulate and Condition Mud, POOH UD Drill Pipe and BHA, Nipple Down Riser, N/U E -line BOP, Run Gauge Ring Junk Basket, RIH w/ Packer. DIMS 11/08/2006 POOH w/ Packer Assembly, M/U RIH w/Clean Out Assembly, Displaced Hole to 13.9 ppg Brine, POOH, N/U SWS. Run GR / JB, POOH, Made Second Run w/ GR/JB. DIMS 11/09/2006 RIH w/Packer Assembly, Attempt to Work Packer to Depth, POOH w/Packer, R/U and Run Packer On 2 7/8" Tubing. R/U SWS w/ GR/CCL to Correlate Packer Setting Depth. DIMS 11/10/2006 Set and Tested Packer, POOH w/Tubing, RIH w/Seal Assemby and 2 7/8", 6.5#, L-80, ELIE, 8 rd, Completion, Space Out, Land Tubing Hanger, Freeze Protect Well, Test Tubing and Annulus to 1,750 psi. DIMS 11/11/2006 Install TWC, R/U Landing Jt, Test TWC, Change Rams, N/U Adapter Flange, Test Pack Off, N/U Tree, Test Tree, Attempt to Pull TWC. AWGRS 11/14/2006 ***ATTEMPT*** UNABLE TO COMPLETE RIG UP DUE TO E -LINE PRIORITY JOB, ON NEXT WELL OVER. RIG UP SLICKLINE UNIT TO PULL TTP. AWGRS 11/15/2006 ***WELL SHUT 1N ON ARRIVAL*** RAN BAILERS AND BAILED APPROX 5 GAL OF SLUGGITS FROM XXN PLUG. AWGRS 11/16/2006 (post rwo) BAILLED SLUGG ITS FROM TOP OF 2-7/8 XXN PLUG. PULLED 2-7/8 XXN PLUG. RAN 2.15" CENT, TEL, SB (LOCATED TT @ 1913' SLM, CORRECTED TO 1917' MD (NO ELM AVAILABLE). TAGGED TD @ 2087' SLM, (CORRECTED 2091' MD) *** WELL LEFT S/I ON DEP, PAD OP NOTIFIED *** AWGRS 11/17/2006 T/I/O= 700/80/n/a Assist E -line w/ LDL. FWHP=500/0/na Page 3 0 • OWDW-SW DESCRIPTION OF WORK COMPLETED AWGRS 11/17/2006 **WELL SHUT-IN AT ARRIVAL T/I 25/0** RST SIGMA LOGGED FROM TD AT 2082 TO 1500 FT USING BORAX FOR A CHANNEL DETECTION LOG. NO ANOMALIES OR CHANNELS OBSERVED. TOOLS WERE SITTING DOWN @ 1980' ELM FOR THE BASELINE TEMP PASS, FIRST KCL PASS & THE FIRST BORAX PASS. IT THEN "BROKE FREE" & WERE ABLE TO CONTINUE DOWN TO 2082'. (POSSIBLE SAND IN THE WELL FROM PRIOR RWO) ***Job complete*** AWGRS 11/17/2006 T/1=120/VAC. Temp=Sl. MIT -IA PASSED to 1650 psi (for R/C). EPA Witnessed by Thor Cutler. Pumped IAP to 1650 psi. Start test. IAP decreased 100 psi in 10 min. Test failed. Pumped IAP to 1680 psi. Start test. IAP decreased 30 psi in 15 min. IAP decreased 10 psi in 2nd 15 min. for a total loss of 30 psi for 30 min. Bled IAP from 1640 psi to 0 psi in 5 min. Applied N2 cap to > 100'. Allowed IAP to bleed off to 0 psi. Final WHPs=170/0. AWGRS 11/18/2006 T/I/O=SSV/0+. Temp=S1. IA FL (DSO call-in). IA FL @ 180'. Page 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Adikk W OWDW-SW OWDW-SW WORKOVER DOYON DRILLING INC. DOYON 16 Spud Date: 6/24/1973 Start: 10/29/2006 End: 11/11/2006 Rig Release: 11/11/2006 Rig Number: 10/31/2006 03:00 - 06:30 3.50 MOB P PRE Bridal Up Blocks, Move Rig Off 7-19A, Spot Rig on Pad and Lay Over Derrick 06:30 - 07:30 1.00 MOB P PRE Install Rear Booster Wheel Assembly on Sub. 07:30 - 10:30 3.00 MOB P PRE Move Rig Off of Drill Site 7 Down Oxbow Road to the Spine Road. Down Spine Road Onto Drill Site 6. 10:30 - 11:00 0.50 MOB P PRE Remove Rear Booster Wheel Assembly. 11:00 - 13:00 2.00 MOB P PRE Raise and Pin Derrick, R/U Rig Floor. 13:00 - 15:30 2.50 MOB P PRE Move Rig to and Spot on Well OWDW-SW. Level Rig 15:30 - 18:00 2.50 MOB P PRE Lay Herculite, Spot and Berm Cuttings Tank. Install Double Annulus Valve. Rig Accecpted at 16:00 Hours. 18:00 - 19:00 1.00 KILL P DECOMP Take on 120 Degree Seawater, Mix Up 100 bbl Safe Surf O Sweep. 19:00 - 21:00 2.00 KILL P DECOMP Hold Pre Spud Meeting, Line Up and Pressure Test Lines to 1,500 psi. Pump 6 bbls Down 1 1/4" CS Hydril Tubing. Line Up and Pump Down 2 3/8" Tubing Taking Diesel Freeze Protect Returns Out Annulus Through Choke Manifold. Pump Sweep Followed by 96 bbls of 120 Degree Seawater. 1,060 psi at 5.5 bpm. 21:00 - 22:30 1.50 KILL P DECOMP Take on 120 Degree 13.9 ppg Mud; Pump 20 bbl Spacer Followed by 13.9 ppg Mud. 1,060 psi at 3.5 bpm. Pump 6 bbls of 13.9 ppg Mud Down 1 1/4" CS Hydril Tubing. Pump 3.5 Circulations of 13.9 ppg Mud. 22:30 - 00:00 1.50 KILL P DECOMP Blow Down Lines and Monitor Well. 0 Pressure and No Flow on Annulus and 2 3/8" Tubing. Slight Flow Out 1 1/4" Tubing Outlet. Fluid Level in 2 3/8" Tubing Dropping Slowly. R/U Hose From 2 3/8" Tubing to 1 1/4" Tubing Outlet. 11/1/2006 00:00 - 00:30 0.50 KILL P DECOMP Allow 13.9 ppg Mud U -Tube Between 2 3/8" Tubing and 1 1/4" Tubing. 00:30 - 02:30 2.00 BOPSUF P DECOMP Blow Down Lines and Open Well. 0 Pressure on 2 3/8" Tubing, Annulus and 1 1/4" Tubing. No Flow. Monitor Well and Assemble 7 1/16" Double Gate, Mud Cross and Single Gate. 02:30 - 03:00 0.50 WHSUR P DECOMP N/D FMC 7 1/16" x 2 1/16" Dual Tree Flange and FMC 2 1/16" Tree. 03:00 - 03:30 0.50 WHSUR P DECOMP Clean and Inspect Wellhead. 1 1/4" CS Hydril Threads in Good Condition, 2 3/8" Tubing Had No Threads Showing and Was Washed. Functioned Lock Down Screws. 03:30 - 20:00 16.50 BOPSUF P DECOMP N/U 7 1/16" DSA, N/U BOP Stack. Remove HCR's and Manual Valves From 13 5/8" BOP Stack. Build Hydraulic Operating Hoses For Rams. Function Test Lines and BOP's. Bleed Down Koomey and Open BOP's and Move Rams. BOP's Configured Annular, Blinds, 1.66" Rams, Mud Cross, Blinds. 20:00 - 20:30 0.50 BOPSUP P DECOMP R/U BOP Test Equipment and Fill BOP Stack. 20:30 - 00:00 3.50 BOPSUF P DECOMP Test 7 1/16" BOP Stack, Choke Manifold, Floor Valves, Upper and Lower IBOP's to 250 psi Low Pressure and 1,750 psi High Pressure Against Cement Plug. Each Test Was Held For 5 Minutes. Good Test No Failures. Test Was Witnessed by Lou Gramaldi with AOGCC, Doyon Toolpusher and BP WSL. 11/2/2006 00:00 - 01:30 1.50 BOPSUF P DECOMP Test 7 1/16" BOP Stack, Choke Manifold, Floor Valves, Upper and Lower IBOP's to 250 psi Low Pressure and 1,750 psi High Pressure Against Cement Plug. Each Test Was Held For 5 Minutes. Good Test No Failures. Test Was Witnessed by Lou Gramaldi with AOGCC, Doyon Toolpusher and BP WSL. Printed: 11/13/2006 10:45:28 AM Legal Well Name: OWDW-SW Common Well Name: OWDW-SW Spud Date: 6/24/1973 Event Name: WORKOVER Start: 10/29/2006 End: 11/11/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 11/11/2006 Rig Name: DOYON 16 Rig Number: 11/2/2006 01:30 - 02:30 1.00 BOPSUF P DECOMP R/D Test Equipment. Blow Down Choke, Choke Line and Kill Line. 02:30 - 06:00 3.50 WHSUR P DECOMP Remove Gravel From Cellar Box. Dig Out and Uncover 7 1/16" 14:30 - 16:00 1.50 CLEAN P DECOMP Tubing Spool and 7 1/16" x 13 5/8" XO Spool. 06:00 - 12:30 6.50 CLEAN P DECOMP Rig Up to pull 1-1/4" CS Hydril. Load, Strap, and Tally 2-7/8" DP. Wait on Orders to from town to pull tubing. 12:30 - 13:00 0.50 CLEAN P DECOMP Drain Stack and P/U 1-1/4" CS Hydril. 13:00 - 13:30 0.50 CLEAN P DECOMP PJSM on pulling and L/D tbg. Go over loading small tbg on pipe skate, Lifting Nubs, spill / drip prevention and well control. Printed: 11/13/2006 10:45:28 AM 13:30 - 14:30 1.00 CLEAN P DECOMP M/U Landing Joint and Engage Tbg in hanger. Pull and L/D 2 Joints of 1-1/4" CS Hydril. Required -2000 lbs to pull tbg to floor. 14:30 - 16:00 1.50 CLEAN P DECOMP M/U Circ Head and circulate 70 bbls of 13.9 ppg Mud. Initial circulation rate were .7 bpm at 700 psi. Shut down and check surface lines to confirm nothing frozen or closed. Continue to circulate, able to get -1.1 bpm at 600 psi. 16:00 - 20:00 4.00 CLEAN P DECOMP Rig Down and Blow Down lines and hoses. Continue to pull and lay down tbg. Recovered 60 Joints of 1 1/4" CS Hydril Tubing. Pin ends had some corrosion on nose of pin. 20:00 - 20:30 0.50 CLEAN P DECOMP R/D 1 1/4" Handling equipment. Clear and clean rig floor. 20:30 - 21:30 1.00 CLEAN P DECOMP Drain BOP stack. Remove 1.66" Rams ans install 2 3/8" Rams. 21:30 - 22:00 0.50 CLEAN P DECOMP R/U test equipment and test 2 3/8" rams to 250 psi low pressure and 1,750 psi high pressure. Each test was held for 5 minutes. Good test. Test was witnessed by Doyon Toolpusher and BP WSL. 22:00 - 22:30 0.50 CLEAN P DECOMP M/U 2 3/8" Spear Assembly. 22:30 - 23:30 1.00 CLEAN P DECOMP Engage 2 3/8" Tubing with Spear Assembly. Back out lock down screws. Tubing came at 6,000# pull. Pulled Seal Assembly to rig floor. Hanger did not pull to rig floor. Seal Assembly did not have groove for lock down pin as shown in manufacturer's drawing. L/D Spear Assembly. 23:30 - 00:00 0.50 CLEAN P DECOMP R/U to circulate bottoms up. 11/3/2006 00:00 - 01:30 1.50 CLEAN P DECOMP Cross over sub for 2 3/8" AB DSS Tubing had been recut to 2 3/8" ELIE. Gather subs to make a XO assembly. 01:30 - 03:00 1.50 CLEAN P DECOMP Circulate bottoms up. 2 bpm with 440 psi. R/D and Blow down lines. 03:00 - 06:30 3.50 CLEAN P DECOMP POOH laying down 2 3/8", 4.7#, AB DSS Tubing. Tubing has some corrosion in the connections. 59 joints plus a cut joint @ 16.23'. Cut was very clean and very little flare. 06:30 - 07:00 0.50 CLEAN P DECOMP Clean and Clear Rig Floor. While waiting on fishing tool grapple. 07:00 - 08:30 1.50 CLEAN P DECOMP P/U joint of drill pipe and make up Itco spear for 3-1/8" ID. RIH and engage hanger. Make multiple attempts to engage spear into hanger. Grapple too small. Replace grapple with next size larger and RIH. Engage hanger and latch on first try. Pull hanger to floor with little to no over pull. 08:30 - 09:00 0.50 CLEAN P DECOMP Continue with Clean and Clear Rig Floor. 09:00 - 10:00 1.00 BOPSUF P DECOMP C/O Pipe Rams to 2-7/8" and Pressure Test. 10:00 - 11:30 1.50 CLEAN P DECOMP M/U HES Retrievable Bridge Plug to 2-7/8" PAC DP. RIH and position RBP 3 joints below the floor and set. Top of RBP at 93.27'. 11:30 - 12:00 0.50 CLEAN P DECOMP POOH and lay down 3 joints of PAC DP. L/D RBP running Printed: 11/13/2006 10:45:28 AM Legal Well Name: OWDW-SW Common Well Name: OWDW-SW Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 11/3/2006 11:30 - 12:00 0.501 CLEAN P 12:00 14:00 2.001 BOPSUR P 14:00 - 17:00 1 3.001 BOPSUR P 17:00 - 20:00 1 3.001 BOPSUR P 20:00 - 22:00 1 2.001 BOPSUR P 22:00 - 00:00 1 2.001 BOPSUR P 111/4/2006 100:00 - 01:30 1 1.501 BOPSUR P 01:30 - 02:00 1 0.501 BOPSUR P 02:00 - 04:00 1 2.001 BOPSUR P 04:00 - 09:30 1 5.501 BOPSUR P 09:30 - 10:00 1 0.501 BOPSUP 10:00 - 11:30 1 1.501 BOPSU N SFAL 11:30 - 12:00 1 0.501 BOPSUR N I SFAL 12:00 - 15:30 1 3.501 BOPSUR P 15:30 - 16:00 0.50BOPSU P 16:00 - 17:00 1.00 CLEAN P 17:00 - 17:30 0.50 CLEAN P 17:30 -18:30 1.00 CLEAN P 18:30 - 19:00 0.50 CLEAN P 19:00 - 20:00 1.00 CLEAN P 20:00 - 22:00 1 2.00 CLEAN I P 22:00 - 23:00 1 1.00 CLEAN I P Spud Date: 6/24/1973 Start: 10/29/2006 End: 11/11/2006 Rig Release: 11/11/2006 Rig Number: DECOMP tool. Pressure Test RBP to 1000 psi for 10 mins - Good Test. DECOMP Blow down choke & kill lines and hole fill line. Flush and clean out 7-1/16" BOP Stack and drain entire BOP system. DECOMP Break apart and lay down 7-1/16" BOP Stack - Annulur, Double Gate, Mud Cross, Single Gate, and 3k x 5k DSA. DECOMP N/D 7-1/16" x 13-5/8" Tubing Spool to replace pack off. Found pack off different than originally thought it to be. Discuss options with well engineer on how to proceed. DECOMP Install new Packoff in Tubing Spool and check measurements. New Tubing Spool / Packoff requires removing 1" from existing 5 1/2" x 7" Bushing / Packoff assembly. DECOMP R/U Wach's cutter and Proceed with cutting 5 1/2" x 7" Bushing / Packoff assembly. DECOMP Continue cutting 1" off the 5 1/2" x 7" Bushing / Packoff assembly with Wach's cutter. DECOMP R/D Wach's cutter and wipe down 5 1/2" x 7" Bushing / Packoff and slip area to insure no metal shavings. DECOMP N/U 13 5/8" 2K x 11" 5K Tubing spool with Packoff preloaded. Test Packoff Seals to 2,000 psi for 15 Minutes as per FMC procedures. Good Test. DECOMP N/U 13 5/8" 5K BOPE, 11" x 13-5/8" Adapter, Install Manuals and HCR's. Swap Pipe Rams to 2-7/8" VBR's. DECOMP Rig Up Test Equipment and Set Test Plug. DECOMP Attempt to Pressure Test 2-7/8" VBR's with 2-7/8" test joint. Found rams to be leaking. Function rams multiple times and attempt to test again. Drain BOP Stack and inspect rams, nothing found wrong. Close doors and bolt back up. DECOMP Set Test joint in BOP stack again and function pipe rams. Attempt to pressure test and identified leak point coming from between rams. Increase manifold pressure to force rams tighter. Function rams and close against test joint. Able to pressure test rams - holding pressure. DECOMP Pressure Test BOPE 250 psi low / 1750 psi high. Each Test held for 5 mins. Pressure test 2-7/8" VBR's, Annular, blind rams, Choke and Kill HCR's, Choke and Kill Manuals, Choke Valves 1-14, Upper and Lower IBOP, Dart Valve & TIW, and Koomey Unit. All Test passed. Witnessed by BP Wellsite Leader and Doyon Toolpusher. Witness waived by Lou Grimaldi w/ AOGCC. DECOMP Rig Down BOP Test Equipment. DECOMP Clear Ice and Snow from Derrick. DECOMP Pull and L/D test plug. Install wear Bushing. 7.125" ID DECOMP WU HES Running tool and RIH to 93' and engage RBP. Release RBP. POOH and L/D RBP and running tool. DECOMP Clear and Clean Rig Floor. DECOMP WU BHA #1, Overshot Assembly. 4 1/8" Overshot with Extension, Bumper Sub, Oil Jar, XO, 9 x 3 1/8" DC's, XO, Intensifier, XO, Pump Out Sub. Total BHA Lenght = 299.50' DECOMP RIH with BHA #1, Picking up 2 7/8" PAC Drill Pipe to 1,871'. DECOMP Establish Parameters, Up weight 60,000#, Down weight 58,000#, Rotating weight 57,000#. 20 rpm with 1,000 ft/lbs torque. 2 bpm with 900 psi pump pressure. Wash down and tag top of tubing at 1,908' RKB depth. Wash over tubing stub Printed: 11/13/2006 10:45:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: OWDW-SW OWDW-SW WORKOVER DOYON DRILLING INC. DOYON 16 Spud Date: 6/24/1973 Start: 10/29/2006 End: 11/11/2006 Rig Release: 11/11/2006 Rig Number: 11/4/2006 22:00 - 23:00 1.00 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 11/5/2006 00:00 - 02:30 2.50 CLEAN P DECOMP 02:30 - 03:30 1.00 CLEAN P DECOMP 03:30 - 04:30 1.00 CLEAN P DECOMP 04:30 - 06:00 1.50 CLEAN P DECOMP 06:00 - 08:30 2.50 CLEAN P DECOMP 08:30 - 10:30 2.00 CLEAN P DECOMP 10:30 - 12:00 1.50 CLEAN P DECOMP 12:00 -19:30 7.50 CLEAN P DECOMP 19:30 - 22:00 2.50 CLEAN P DECOMP 22:00 - 23:00 1.00 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 11/6/2006 00:00 - 02:00 2.00 CLEAN P DECOMP 02:00 - 02:30 0.50 CLEAN P DECOMP 02:30 - 03:30 1.00 CLEAN P DECOMP 03:30 - 07:00 3.50 CLEAN P DECOMP 07:00 - 07:30 0.50 CLEAN P DECOMP 07:30 - 09:00 1.50 CLEAN P DECOMP 09:00 - 10:30 1.50 CLEAN P DECOMP 10:30 - 12:30 2.00 CLEAN P DECOMP 12:30 - 14:00 1.50 CLEAN P DECOMP 14:00 - 14:30 0.50 CLEAN P DECOMP with 1/2 bpm with 260 psi pump pressure. Pump pressure increased to 520 psi. P/U on string Saw 1,000 - 2,000# overpull, and pressure decrease. Circulate and condition mud. 2 bpm at 900 psi pump pressure. POOH laying down 2 7/8" PAC Drill Pipe from 1,908' to 299' L/D BHA #1, Recovered 16' of 2 3/8" tubing and 11.3' of seal assembly. Clear and clean rig floor. Gather BHA #2. P/U BHA #2, MM PKR Mill w/ 2 1/4" Stinger, XO, 4 3/4" Stab, 2 x Boot Basket, XO, Oil Jar, XO, 9 x 3 1/8" DC's, Pump Out Sub. Total BHA Length = 290.15' P/U DP from shed and RIH to 1824' Slip and Cut 135' of Drilling Line. Lub Rig. Continue to RIH to 1924', Tag Up on Packer, WU XO for Top Drive. Take Initial Parameters. Up Wt = 55,000 lbs, Down Wt = 62,000 lbs, Rot Wt = 65,000 lbs, 2.4 bpm at 450 psi, 2000 ftlbs of free torque at 80 rpms. Mill Packer from 1,925' MD to 1,928' MD. 4,000 - 10,000 WOB, 2 bpm at 1,000 psi. 40 to 100 rpm. POOH laying down 2 7/8" PAC Drill Pipe. Lay Down BHA #2. Mill was Completly worn, with rounded shoulder. M/U BHA #3, Itco 2.718" Spear, Bumper Sub, Oil Jar, XO, 9 x 3 1/8" DC's, XO, Intensifier, XO, Pump Out Sub. Total BHA Lenght = 298.97' RIH Picking up 2 7/8" PAC Drill Pipe to 1,900' Establish Parameters, 57,000# Up Weight, 58,000# Down Weight, 1.5 bpm with 1,700 psi pump pressure. Wash down and engage fish at 1,928'. S/O to 50,000# and cock jars, P/U to 100,000# and fire jars, P/U to 110,000#, S/O to 50,000#, P/U to 100,000# and fire jars, P/U to 125,000#. Fish came free. Drug up hole for 8' with 15,000# overpull. Continue to pull up with 1,000 - 2,000# overpull. Circulate bottoms up. 2 bpm with 2,000 psi pump pressure. POOH with BHA #3, laying down 2 7/8" PAC Drill Pipe. L/D ITCO Spear and Fish. Length of fish = 21.90'. All of the packer milled except bottom 6" or so of the base. The WLEG was cemented up on the inside and there was - 1-1/2' of cement on the outside of the Tubing Tail around the W LEG. Lengths on Diagram Supplied not consistant with what was pulled. All parts and pieces pulled from well. Clean and Clean Rig Floor. Gather BHA for next run. P/U 5-1/2" Csg Scraper BHA w/ 4-3/4" Bit, 5-1/2" Csg Scraper, XO, 2 x Boot Baskets, XO, Bumper Sub, Oil Jar, XO, 9x3-1/8" DC's, Pump Out Sub. Total Length = 293.74' RIH w/ 2-7/8" PAC DP from Shed. Tag top of cement at 1950' and RKB. M/U Top Drive and Establish Intial Drilling Parameters. Drill Cement from 1950' to 1955' w/ 5,000 lbs WOB, 40 rpm's, and 1,500 ft -lbs torque. Pump Rate = 3.5 bpm at 2410 psi. Circulate around 20 bbl hi visc sweep at 4 bpm and 2760psi. Nothing seen with sweep coming across shakers. Printed: 11/13/2006 10:45:28 AM Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 11/6/2006 14:30 - 16:30 16:30 - 17:30 17:30 - 18:30 i OWDW-SW OW DW -SW WORKOVER DOYON DRILLING INC. DOYON 16 2.001 CLEAN I P 1.00 1 CLEAN I P 1.00 1 CLEAN I P Spud Date: 6/24/1973 Start: 10/29/2006 End: 11/11/2006 Rig Release: 11/11/2006 Rig Number: DECOMP DECOMP DECOMP 11/7/2006 100:00 - 03:00 1 3.001 CLEAN I P I I DECOMP 03:00 - 05:00 1 2.001 CLEAN I P I I DECOMP 05:00 - 07:00 1 2.001 CLEAN I P I I DECOMP 07:00 - 07:30 18:30 19:00 0.50 CLEAN P DECOMP DECOMP 2.00 19:00 19:30 0.50 CLEAN P 09:30 - 11:00 DECOMP CLEAN 19:30 - 22:00 2.50 CLEAN P 1.00 DECOMP P 22:00 - 00:00 2.00 CLEAN P RUNCOMP DECOMP 11/7/2006 100:00 - 03:00 1 3.001 CLEAN I P I I DECOMP 03:00 - 05:00 1 2.001 CLEAN I P I I DECOMP 05:00 - 07:00 1 2.001 CLEAN I P I I DECOMP 07:00 - 07:30 0.50 CLEAN P DECOMP 07:30 - 09:30 2.00 CLEAN P RUNCOMP DECOMP 09:30 - 11:00 1.50 CLEAN P 0.50 DECOMP 11:00 - 12:00 1.00 CLEAN P 03:30 - 05:00 DECOMP 12:00 - 13:00 1.00 RUNCOMP RUNCMP RUNCMP 13:00 - 14:00 1.00 RUNCO RUNCMP 14:00 17:00 3.00 BUNCO RUNCMP 17:00 - 20:00 1 3.001 RUNCOMP I I RUNCMP 20:00 - 22:00 1 2.001 RUNCOMP I I RUNCMP 22:00 - 00:00 1 2.001 RUNCOMP I I RUNCMP 11/8/2006 00:00 - 01:30 1.50 RUNCOMP RUNCMP 01:30 - 03:00 1.50 RUNCOMP RUNCMP 03:00 - 03:30 0.50 RUNCOMP RUNCMP 03:30 - 05:00 1.50 RUNCOMP RUNCMP 05:00 - 07:00 2.00 RUNCOMP RUNCMP 07:00 - 10:00 3.00 RUNCOMP RUNCMP 10:00 -12:30 1 2.501 RUNCOMP I I RUNCMP Break Off and Blow Down Top Drive. POOH from 1950'. L/D BHA #4, Clean Out BHA with Scraper. M/U BHA #5, 4-3/4" Bit, XO, 2 x Boot Baskets, XO, Oil Jar, XO, 9 x 3-1/8" DC's, Pump Out Sub. Total BHA Length = 283.01' Service Top Drive. Clear and Clean Rig floor. RIH w/ 2-7/8" PAC DP to 1,949'. M/U Top Drive and Establish Parameters, Up weight 56,000#, Down weight 58,000#, Rotating weight 57,000#, 3.5 bpm at 2,450 psi pump prssure, 40 rpm with 1,000 ft/lbs torque. Drill Cement from 1,955' to 1,970'. WOB 5,000# - 6,000#, 60 rpm with 1,000 - 2,000 ft/lbs torque. 3.5 bpm with 2,450 psi pump pressure. Drill Cement from 1,970' to 1,989', WOB 5,000 - 7,000#, 60 rpm at 1,000 - 2,000 ft/lbs of torque, 3.5 bpm with 2,450 psi pump pressure. Wash Sand from 1,989' to 2,070' RKB. WOB 0 - 4,000#, 60 rpm with 1,000 - 1,500 ft/lbs of torque, 3.5 bpm with 3,450 psi pump pressure. No Losses While Drilling Cement of Washing Sand. Pump 20 bbl high vis sweep around. Circulate well clean. 3.5 bpm with 2,470 psi pump pressure. Condition Mud to 13.9 ppg. B/O and B/D Top Drive. Monitor Well Prior to POOH. POOH and L/D 2-7/8" PAC DP. L/D 3-1/8" DC's and Drill Out BHA. Clean and Clear Rig Floor. Gather Jewelry in Pipe Shed and Lay Out in Order. WU WLEG / XN Nipple to 5-1/2" x 2-7/8" Packer Assembly and Baker Lock. N/D Flow Riser from BOP Stack and Nipple Up Shooting Flange to the top of the Hydril. PJSM w/ SLB E -Line, N/U Riser, Pump in Sub, E -Line BOP and Pack Off / Grease Head, and Gauge Ring Junk Basket Assembly, Test Surface Equipment to 1,500 psi. RIH w/4.805" Gauge Ring to 545' Twice, No -Go POOH, M/U 4.75" Gauge Ring, RIH to 1,917', POOH, No Junk in Basket. B/O L/D Gauge Ring, Junk Basket, M/U Setting Tool, Firing Head, GR, CCL, Dumped 8' Sluggets on XN Plug. RIH w/Baker Packer on SWS E -line, Attempted to Reach Minimum Depth of 1,840'. Unable to go Past 1,797' with Packer. POOH. L/D Baker Packer Assembly, R/D SWS Equipment. N/D Shooting Flange, N/U Riser and Test Air Boots for Leaks. P/U BHA to Rig Floor. P/U Scraper BHA and 9 - 3 1/8" Drill Collars. P/U 2 7/8" Drill Pipe to 2,060'. Circulate Mud around while rotating and recipricating drill pipe from 1990' to 1900' and GL. 3.5 bpm at 2450 psi. Circulate 35 bbl of 13.9 NaCl / NaBr Brine at 3.5 bpm and 2150 psi. while working pipe. L/D 3 joints of drill pipe and M/U to Top Drive. Work Pipe from 1900'- 1810' and GL. Circulate another 25 bbls of 13.9 ppg Brine. L/D 3 additional joints of Printed: 11/13/2006 10:45:28 AM i Legal Well Name: OWDW-SW Common Well Name: OWDW-SW Spud Date: 6/24/1973 Event Name: WORKOVER Start: 10/29/2006 End: 11/11/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 11/11/2006 Rig Name: DOYON 16 Rig Number: 11/8/2006 10:00 - 12:30 2.50 RUNCO RUNCMP DP. Work Pipe from 1810'-1720' and GL. Circulate 50 bbls. L/D 3 joints of DP. Work Pipe from 1720 - 1630' and GL. Circulate 75 bbls at 4 bpm and 2420 psi. 12:30 - 13:00 0.50 RUNCOMP RUNCMP Flow Check Well. B/O and B/D Top Drive. 13:00 - 16:30 3.50 RUNCOhV RUNCMP POOH and L/D 2-7/8 DP and Scraper BHA. Flow Check Well every 15 its. 16:30 - 17:30 1.00 RUNCOhV RUNCMP N/D Riser, N/U Shooting Flange. 17:30 - 20:30 3.00 RUNCOMP RUNCMP R/U SWS E -Line, Pump in Sub, E -Line BOP and Pack Off / Grease Head, P/U Gauge Ring Junk Basket. Pressure Test Surface Equipment to 1,500 psi. 20:30 - 22:30 2.00 RUNCOMP RUNCMP RIH With 4.5" Gauge Ring, Junk Basket to 1,940' Slick Going In, POOH Tool Stuck at 975', Worked Free POOH to Surface. Junk Basket Had Approx 1/2 gal of Shale and Gravel. Decision Made for Second Run 22:30 - 00:00 1.50 RUNCOMP RUNCMP RIH With 4.75" GR / JB to 1,920' Slick Going In and Coming Out. 11/9/2006 00:00 - 01:30 1.50 RUNCOMP RUNCMP Clean Out Junk Basket, Retrieved Few Pieces of Shale. R/D GR/JB, Rebuild Rope Socket Weak Point. 01:30 - 03:00 1.50 RUNCOMP RUNCMP Test Firing Head M/U Packer to Running Assembly. 03:00 - 04:00 1.00 RUNCOMP RUNCMP RIH w/Packer Assembly to 1,780' Packer Hung Up, Pulled Up Smooth. Attempted to RIH Several Times, 04:00 - 05:00 1.00 RUNCOMP RUNCMP Reviewed Log, Discussed Options With Rig Team. 05:00 - 07:00 2.00 RUNCOMP RUNCMP Attempt to Work Threw Tight Spot at 1,780'w/ packer on E -Line. 07:00 - 08:00 1.00 RUNCOMP RUNCMP POOH w/ Packer Assembly 08:00 - 09:00 1.00 RUNCOMP RUNCMP R/D SWS and L/D Packer Assembly. 09:00 - 09:30 0.50 RUNCOMP RUNCMP N/D Shooting Flange, N/U Riser. 09:30 - 10:30 1.00 RUNCO P RUNCMP Remove 2 7/8" Drill Pipe f/Pipe Shed, R/U to Run 2 7/8",6.5#, L-80 EUE, 8 rd Tubing Work Sting. 10:30 - 11:00 0.50 RUNCOMP RUNCMP Service Top Drive, Draworks, and Blocks. 11:00 - 13:00 2.00 RUNCOMP RUNCMP Wait On Hydraulic Setting Tool. Continue to Work on Light Maintenance and Inspections, Complete Work Orders. 13:00 - 16:00 3.00 RUNCO P RUNCMP M/U Packer and XN Nipple, Tail Pipe and WLEG, Running Tool and RIH w/ 2 7/8" Tubing. Collars Hanging Up In 5.5" Csg in Well Head. RIH with 3jts 16:00 - 17:00 1.00 RUNCO P RUNCMP Discuss Options w/Rig Team, Ordered Out a 5 1/8" ID Wear Ring From FMC. 17:00 - 17:30 0.50 RUNCOMP RUNCMP L/D 1 it Tubing, Pulled 2 its and Packer Assembly Out of Hole. Pulled 7 1/8" Wear Ring. Installed 5 1/8" Wear Ring. 17:30 - 21:30 4.00 RUNCOMP RUNCMP RIH With W LEG, XN Nipple and Sealbore Packer Assembly on 2-7/8", 6.5'#, L-80, EUE 8rd Tubing to Packer Setting Depth of 1,900' RKB. 21:30 - 23:00 1.50 RUNCOMP RUNCMP R/U SWS With TIW, Pump In Sub, Flow Tubes and Pack Off. 23:00 - 00:00 1.00 RUNCOMP RUNCMP RIH w/ Gamma / CCL to Correlate Packer Setting Depth. 11/10/2006 00:00 - 01:30 1.50 RUNCOMP RUNCMP Continue to POOH With Wire Line. R/D SWS. 01:30 - 02:00 0.50 RUNCOMP RUNCMP Dropped 3/4" Ball, R/U Circulating Lines and Test Equipment. Set Packer at 1,872' ( 1900' RKB) mid element Refenced From Ground Level, Pressured up to 2,000 psi to Set Packer, P/U to Shear out and Picked up S with Tubing Sting. RKB - GL = 27.5'. 02:00 - 03:30 1.50 RUNCOMP RUNCMP Test Packer to 1,300 psi with 13.9 ppg Brine in Hole, for 30 minutes. R/D B/D Circ Lines and Test Equipment, 03:30 - 05:00 1.50 RUNCO RUNCMP POOH and Stand Back 2 7/8" Tubing. Printed: 11/13/2006 10:45:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Adak OW DW -SW OW DW -SW WORKOVER DOYON DRILLING INC. DOYON 16 11/10/2006 05:00 - 05:30 0.50 RU 18:00 - 19:00 05:30 - 08:00 2.50 RU 21:00 - 21:30 08:00 - 09:30 1.50 RU 09:30 - 11:30 2.00 RU 11:30 14:00 2.50 RU 14:00 - 14:30 0.50 RU 14:30 - 15:30 1.00 RU 15:30 - 16:30 1.00 16:30 - 18:00 1.50 18:00 - 19:00 1.00 19:00 - 20:00 1 1.00 Spud Date: 6/24/1973 Start: 10/29/2006 End: 11/11/2006 Rig Release: 11 /11/2006 Rig Number: RUNCMP Clear and Clean Rig Floor, Pull Wear Ring. RUNCMP M/U Seal Assembly, X Nipple, RIH w/2 7/8" 6.5#, EUE, L-80 8 rd Tubing and RIH to 1,334'. RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 01:00 - 03:30 1 2.501 WHSUR I P I J RUNCMP 03:30 - 07:00 1 3.501 WHSUR I P I I RUNCMP R/U Camco Spooling Unit. Start running two strings of 3/8" SS Control Line at the connection between Joints 43 and 44. Dual Check Valves were run on the end of each line. Three SS Bands were used on the top of Joint #43 and a Cannon Clamp used between Joints 43 and 44. Continue to RIH w/ 2 7/8" Completion to 1900' RKB. M/U Circulating head to Jt 60, Obtain Parameters - P/U 50,000#, S/O 47,000#, 1 bpm, 300 psi, Attempt to Sting Seal Assembly into Packer, Stacked 7,000# to 10,000# Down Weight, P/U and Repeat Process Three Times with No Pressure Increase. P/U and Set Slips Rotate Pipe 1/4 Turn, Attempt to Sting in. Repeat Process . Continue to Attempt to Sting into Packer Rocking Tubing String w/ Pipe Handler. R/D Circulating Lines, WU XO to Space Out jt to allow Top Drive to Screw into Tubing String, Band Control Line to Space Out Joint. Cut Control lines loose from Sheeve and Spooler. Band all the way up Space Out Joint plus -5 ft extra. M/U Top Drive to enable Rotation of Pipe, Establish Pump Rate at 2 bpm and 350 psi. Establish Rotation at 5 rpm's and <1000 ft/lbs torque. S/O slowly while rotating and pumping. Stab into Packer W/Seal Assembly. Shut -down pumps and rotation as soon as Seal Assembly enter packer. Confirm Space Out for Seal Assembly stung into packer. L/D Tubing its 59 and 60, P/U it 64 for a space out. No -Go on the Seal Locator Assembly will spaced off - 1 foot above packer. M/U 2-7/8" Landing Joint w/ 4-1/8" LH ACME Thread to Hanger. M/U Tubing Hanger and Pup to Tubing String. Place 2 SS Bands on Last Full Joint below hanger. M/U Control Lines through hanger and Test each port to 5000 psi for 5 mins. Lower Hanger into BOP Stack so Seal Assembly just above packer. Close annular around tubing and attempt to reverse ciruclate. Leaking by annular due to control lines. Unable to move hanger below annular. Change to convention circulation. Pump 20 bbl Hi -Vis Sweep. Followed by 120 Deg Sea Water at 3 bpm w/100 psi. Followed by 10 bbl Hi -Vis Sweep. R/U Little Red and Pump 49 bbls 80 deg Diesel at 2 bpm w/70 psi. Confirm good diesel at surface. Land Tubing Hanger, RILDs. R/U to Test Tubing and Annulus. Test Tubing and Annulus to 1,750 psi for 30 Minutes each. Rig Down Landing Joint and Testing Equipment. Install TWC Test to 1,000 psi f/10 minutes, B/D and R/D Little Red, Pull Landing it. Clean out BOP Stack of Diesel, Clean Out Drip Pan below Rig Floor, C/O BOP Rams to 3.5"x 6" VBRs, N/D BOPs, N/D 11" XO Spool. N/U Adapter Flange and Test Pack Off to 5000 psi for 30 mins. Printed: 11/13/2006 10:45:28 AM 20:00 - 21:00 1.00 RUNCOMP RUNCMP 21:00 - 21:30 0.50 RUNCOMP RUNCMP 21:30 - 23:30 2.00 RUNCOMP RUNCMP 23:30 - 00:00 0.50 RUNCOhF RUNCMP 11/11/2006 00:00 - 01:00 1.00 WHSUR P RUNCMP 01:00 - 03:30 1 2.501 WHSUR I P I J RUNCMP 03:30 - 07:00 1 3.501 WHSUR I P I I RUNCMP R/U Camco Spooling Unit. Start running two strings of 3/8" SS Control Line at the connection between Joints 43 and 44. Dual Check Valves were run on the end of each line. Three SS Bands were used on the top of Joint #43 and a Cannon Clamp used between Joints 43 and 44. Continue to RIH w/ 2 7/8" Completion to 1900' RKB. M/U Circulating head to Jt 60, Obtain Parameters - P/U 50,000#, S/O 47,000#, 1 bpm, 300 psi, Attempt to Sting Seal Assembly into Packer, Stacked 7,000# to 10,000# Down Weight, P/U and Repeat Process Three Times with No Pressure Increase. P/U and Set Slips Rotate Pipe 1/4 Turn, Attempt to Sting in. Repeat Process . Continue to Attempt to Sting into Packer Rocking Tubing String w/ Pipe Handler. R/D Circulating Lines, WU XO to Space Out jt to allow Top Drive to Screw into Tubing String, Band Control Line to Space Out Joint. Cut Control lines loose from Sheeve and Spooler. Band all the way up Space Out Joint plus -5 ft extra. M/U Top Drive to enable Rotation of Pipe, Establish Pump Rate at 2 bpm and 350 psi. Establish Rotation at 5 rpm's and <1000 ft/lbs torque. S/O slowly while rotating and pumping. Stab into Packer W/Seal Assembly. Shut -down pumps and rotation as soon as Seal Assembly enter packer. Confirm Space Out for Seal Assembly stung into packer. L/D Tubing its 59 and 60, P/U it 64 for a space out. No -Go on the Seal Locator Assembly will spaced off - 1 foot above packer. M/U 2-7/8" Landing Joint w/ 4-1/8" LH ACME Thread to Hanger. M/U Tubing Hanger and Pup to Tubing String. Place 2 SS Bands on Last Full Joint below hanger. M/U Control Lines through hanger and Test each port to 5000 psi for 5 mins. Lower Hanger into BOP Stack so Seal Assembly just above packer. Close annular around tubing and attempt to reverse ciruclate. Leaking by annular due to control lines. Unable to move hanger below annular. Change to convention circulation. Pump 20 bbl Hi -Vis Sweep. Followed by 120 Deg Sea Water at 3 bpm w/100 psi. Followed by 10 bbl Hi -Vis Sweep. R/U Little Red and Pump 49 bbls 80 deg Diesel at 2 bpm w/70 psi. Confirm good diesel at surface. Land Tubing Hanger, RILDs. R/U to Test Tubing and Annulus. Test Tubing and Annulus to 1,750 psi for 30 Minutes each. Rig Down Landing Joint and Testing Equipment. Install TWC Test to 1,000 psi f/10 minutes, B/D and R/D Little Red, Pull Landing it. Clean out BOP Stack of Diesel, Clean Out Drip Pan below Rig Floor, C/O BOP Rams to 3.5"x 6" VBRs, N/D BOPs, N/D 11" XO Spool. N/U Adapter Flange and Test Pack Off to 5000 psi for 30 mins. Printed: 11/13/2006 10:45:28 AM M Legal Well Name: OWDW-SW Common Well Name: OWDW-SW Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 11/11/2006 03:30 - 07:00 3.50 WHSUR P 07:00 09:30 2.50 WHSUR P 09:30 - 11:30 2.00 WHSUR P 11:30 - 12:00 1 0.501 RIGD I P Spud Date: 6/24/1973 Start: 10/29/2006 End: 11/11/2006 Rig Release: 11 /11/2006 Rig Number: RUNCMP Terminate and Tie In Control Lines. N/U 2-9/16" Tree. RUNCMP R/U Test lines and Fill Tree w/ diesel. Test Tree to 5000 psi for 30 mins. RUNCMP P/U DSM Lubricator and Attempt to pull TWC. Unable to latch into TWC due to being packed w/ grease from tree. Make attempt to clean out with suction hose and try again. Still unable to pull TWC. Consult w/ Wells Group and Town. Wells Group will handle getting TWC out. L/D Lubricator. POST Finish Rig Down in Cellar and Secure Well. Release Rig at 12:00 hrs 11/11/06 Printed: 11/13/2006 10:45:28 AM l STATE OF ALASKA OvV ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state,ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska) Inc. 4 FIELD /UNIT !PAD: Prudhoe Bay / PBU / OWDW qq t�� DATE: 11!17/06 ��V W_5W OPERATOR REP: Andrea Hughes AOGCC REP: Va Packer Depth I Pretest Initial 15 Min. 30 Min. Wel1JOWDW-NA Type Inj. I N I TVD 1 1,900'1 Tubing 1 490 4901 4901 4901 Interval O P.T.D.1002400 I Typetest I P I Test psi 1 4751 A 1 1 1,6701 1,6501 1,640 P/FJ P Notes: EPA Witnessed MIT -IA for Regulatory Compliance. WeIIJOWDW-SA Type lnj. I N I TVD 1 1,898'1 Tubing 1 1801 2201 2501 2701 Interval O P.T,D. 1002380 I Typetest I P I Test psi 1 4751 A 1 1 1,6801 1,6501 1,6401..P/FJ P Notes: EPA Witnessed MIT -IA for Regulatory Compliance. WellJOWDW-Sd Type Inj. I N I TVD 1 1,885-1 Tubing 1 5801 5801 5801 5801 Interval O P.T.D.1002390 I Typetest I P I Test psi 1 471 IA 1 1 1,6601 1,5701 1,550 P/FJ P Notes: EPA Witnessed MIT -IA for Regulatory Compliance. Well I Type Inj. I TVD Tubing Interval P.T,D.1 I Type test I I Test psil TRUEJ IA I P/F Notes: Weill Type Inj. I I TVD I I Tubing I I I I Interval P.T,D.1 Type test I I Test psi I I A I I I I P/F Notes: Test Details: TYPE INJ Codes TYPE TEST Codes F = Fresh Water Inj M = Annulus Monitoring G = Gas Inj P = Standard Pressure Test S = Salt Water Inj R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey D = Differential Temperature Test Notes If the test was not ACGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2006-1117_M IT_PBU_OW D W-SE.xIs INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) by 0 10 0 June 1, 2006 Steve McMains Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Monthly Injection Report, Fluid Disposal Wells Dear Mr. McMains: BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Enclosed is the Monthly Injection Report (Form 10-406) for the Oily Waste Disposal Wells located in the Prudhoe Bay Unit for the month of May 2006. If you have questions, please call me at 564-4692. Sincerely, Michael L. Bill Staff Engineer Enclosures cc: Gary Benson, MB 12-4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 Name of Operator: Field and Pool: Month and Year: BP Exploration (Alaska), Inc. Prudhoe Bay, Prudhoe Undefined May, 2006 1. Well No. 2. API No. 3. Type 4. Field & 5. Method 6. Days TUBING PRESS. CASING PRESS. DAILY AVG. INJ. TOTAL MONTHLY INJ. 50-XXX-XXXXX-XX-XX (see Pool Code (see in Oper. 7. MAX 8. AVG 9. MAX 10. AVG 11. LIQUID 12. GAS 13. LIQUID 14. GAS instruct.) instruct.) PSIG PSIG PSIG PSIG (MCF) (BBL) (BBL) (MCF) OWDW-NW 029-21819-00-00 5 640036 9 31 1,001 658 47 13 2,095 0 64,931 0 U :r CC 100 -23`6 OWDW-SW 029-21817-00-00 5 640036 8 0 109 16 5 4 0 0 0 0 U :yC IVU-�o3q OWDW-SE 029-21818-00-00 5 640036 9 31 1042* 716 45 25 2,141 0 66,381 0 Excludes erroneous pressures recorded during valve maintenance. is I hereby certify that the foregoing is true and correct to the best of my knowledge. 15. Printed Name: Michael L. Bill Title: Staff Engineer Signature: Date: D 41Q/10 TOTAL 131,312 0 Form 10-406 Rev. 12/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate UT -C-) kOb -93$ • • bpBP Exploration (Alaska) Inc. Endicott -Prudhoe Bay 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 Confidential May 8, 2006 Mr. William Van Dyke Acting Director, Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 Sag Delta North Well Testing Information - April, 2006 Dear Sir or Madam, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for April, 2006. The attached information includes cumulative produced volumes, a summary of the operational activities and a complete set of well test results used for production allocation. Sincerely, Jon Denis ACT East Subsurface Team Lead JRD/MSB xc: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission Endicott File • • Sag Delta North Production Summary for April, 2006 April, 2006 Production Summary Number of Well Oil STB NGL STB Gas MMSCF GOR SCF/STB Water Cut 2-38/SN-1 2-321SN-3 0 1 5530 0 1 30 .000 1 3.778 1 683 90 Total / Avg. 1 5,530 1 30 1 3.778 1 683 90 Aril Accepted Well Tests Well Number of Tests 2-38/SN-01 0 2-32/SN-03 2 Operations Summary 2-38/SN-1 shut in pending well intervention. 1-17/SN-2 Plugged and abandon, 1/24/97 JRD/CLP ec: M. S. Broacha (w/o attachments) C. Ploegstra (w/o attachments) cc: Sag File 35.02 "State Reports" (w/aftachments) BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-32/SAG DELTA #3 April, 2006 OIL NGL GAS WTR LD HRS PSIG DEGF 1 201 1 134 2,085 0 24.00 309 2 187 1 124 2,003 0 23.00 309 3 189 1 124 2,095 0 24.00 307 4 184 1 119 2,100 0 24.00 296 5 178 1 114 2,105 0 24.00 307 6 172 1 109 2,111 0 24.00 307 7 167 1 104 2,116 0 24.00 312 8 169 1 107 2,050 0 24.00 306 9 171 1 110 1,984 0 24.00 307 10 173 1 112 1,918 0 24.00 308 11 175 1 115 1,852 0 24.00 307 12 177 1 118 1,787 0 24.00 311 13 179 1 121 1,721 0 24.00 307 14 181 1 124 1,655 0 24.00 303 15 183 1 127 1,589 0 24.00 290 16 186 1 129 1,523 0 24.00 289 17 188 1 132 1,458 0 24.00 310 18 190 1 135 1,392 0 24.00 309 19 190 1 135 1,392 0 24.00 308 20 190 1 135 1,392 0 24.00 307 21 190 1 135 1,392 0 24.00 308 22 190 1 135 1,392 0 24.00 306 23 190 1 135 1,392 0 24.00 305 24 190 1 135 1,392 0 24.00 307 25 190 1 135 1,392 0 24.00 309 26 190 1 135 1,392 0 24.00 306 27 190 1 135 1,392 0 24.00 307 28 190 1 135 1,392 0 24.00 305 29 190 1 135 1,392 0 24.00 307 30 190 1 135 1,392 0 24.00 308 31 0 0 0 0 0 0.00 0 TElTAL,3Q 30 3x78 LL _ 5Q 59t0 BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION April, 2006 DAY OIL NGL's GAS (mcf) WTR 201 1 134 2,085 187 1 124 2,003 189 1 124 2,095 184 1 119 2,100 178 1 114 2,105 172 1 109 2,111 167 1 104 2,116 169 1 107 2,050 171 1 110 1,984 173 1 112 1,918 175 1 115 1,852 177 1 118 1,787 179 1 121 1,721 181 1 124 1,655 183 1 127 1,589 186 1 129 1,523 188 1 132 1,458 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 190 1 135 1,392 0 0 0 0 ®1Ak� BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 April, 2006 OIL NGL GAS WTR LD HRS • PSIG DEGF 1 0 0 0 0 0 0.00 0 2 0 0 0 0 0 0.00 0 3 0 0 0 0 0 0.00 0 4 0 0 0 0 0 0.00 0 5 0 0 0 0 0 0.00 0 6 0 0 0 0 0 0.00 0 7 0 0 0 0 0 0.00 0 8 0 0 0 0 0 0.00 0 9 0 0 0 0 0 0.00 0 10 0 0 0 0 0 0.00 0 11 0 0 0 0 0 0.00 0 12 0 0 0 0 0 0.00 0 13 0 0 0 0 0 0.00 0 14 0 0 0 0 0 0.00 0 15 0 0 0 0 0 0.00 0 16 0 0 0 0 0 0.00 0 17 0 0 0 0 0 0.00 0 18 0 0 0 0 0 0.00 0 19 0 0 0 0 0 0.00 0 20 0 0 0 0 0 0.00 0 21 0 0 0 0 0 0.00 0 22 0 0 0 0 0 0.00 0 23 0 0 0 0 0 0.00 0 24 0 0 0 0 0 0.00 0 25 0 0 0 0 0 0.00 0 26 0 0 0 0 0 0.00 0 27 0 0 0 0 0 0.00 0 28 0 0 0 0 0 0.00 0 29 0 0 0 0 0 0.00 0 30 0 0 0 0 0 0.00 0 31 0 0 0 0 1 0.00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 w 1.100 1.000 0 U. 0 r- 0.900 0 4 ommull." Me 0.700 1 FINAL ENDICOTT OIL ALLOCATION FACTORS April 2006 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 Day o Series E E by 0 2-32 • • MPI - 5/8/2006 12:25:24PM Endicott Historical Well Tests Report 4/1/2006.4/30/2006 1d 1,595] 88.00_.. 190 1,392 1,5821 ...711. 104 312 152 268 .146 _. 4174 4055 2,639 1,658 4/7/20Q6 200'QOAM LF 2,294 92.70 LF 0Ye 2.816 Y. 122 2 624..,_104�_._v..._.313�4_.__._. 161 267-_...._...�142� ..,...,_._4,115y_�_._ 4,025 1,503 1,636 0 BP Exploration Page 1 of 1 Endicott, Alaska Reply To Attn Of: • • UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION 10 1200 Sixth Avenue Seattle, WA 98101 OCE 082 2 6 AFF 2006 CERTIFIED MAIL - RETURN RECEIPT REQUESTED Bryan Collver Greater Prudhoe Bay Environmental Advisor BP Exploration (Alaska) Inc.BPXA 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 n' IP 41-111, Re: Mechanical Integrity Witnessed Tests Class I Underground Injection Well, Permit No. AK -1I004 -SW Well Location: Pad 3, Prudhoe Bay Oil Field, North Slope, Alaska Dear Mr. Collver: This letter is in response to the Region 10 Environmental Protection Agency (EPA) witnessed mechanical integrity tests at Prudhoe Bay Field Pad 3. The test was performed on one (1) Class I well (AK1I004-SW) during April 21 through April 22, 2006. An EPA inspector representative witnessed the tests that show AK1I004-SW Class I well tests demonstrated mechanical integrity. By this letter, EPA hereby authorizes injection in the above-mentioned well (AK1I004-SW) that has demonstrated mechanical integrity. EPA appreciates the efforts taken by BPXA to coordinate tests that increase efficiencies and reduce travel expenses of the EPA. If you have any questions or need more information, please call Thor Cutler at (206) 553-1673. Sincerely, r Michael A. Bussell, Director Office of Enforcement and Compliance cc: John Norman, AOGCC, Anchorage 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska) Inc. Zel �t 1��4��, FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Prudhoe Bay! PBU / OWDW 03/03/06 Mike Bill Packer Depth Pretest Initial 15 Min. 30 Min. Well OWDW-N Type Inj. N I TVD 1 1,900'1 Tubing 1 1001 1101 1201 120 Interval 1 P.T.D. 1002400 I Typetest P I Test psi 1 1,5001 IA 1 01 1,6001 1,5201 1,510 P/FJ P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. Well OWDW-S Type Inj. I N I TVD 1 1,898'1 Tubing 1 4801 4801 4801 4801 Interval 1 P.T.D.1002380 I Typetest I P I Test psil 1,5001 IA 1 101 1,6001 1,5501 1,550 P/FJ P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. Well OWDW-S Type Inj. I N I TVD 1 1,8851 Tubing 1 5501 5501 5501 5501 Interval 1 P.T.D.1002390 I Typetest I P I Test psi 1 1,5001 IA 1 01 1,6101 1,5301 1,520 P/FJ P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. Well I Type Inj. TVD I I Tubing I I I I I Interval P,T.D I Typetestl I Test psi I I IA I I I I I P/F Notes: Weill Type Inj. TVD Tubing I Interval P.T.D.1 Typetest Test psi IA I P/F Notes: Test Details TYPE INJ Codes TYPE TEST Codes F = Fresh Water Inj M = Annulus Monitoring G = Gas Inj P = Standard Pressure Test S = Salt Water Inj R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2006-0303 MIT PBU OWDW-SE.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) 0 • AOGCC Memorandum Date: 3/6/2006 To: Well File — PBU OWDW-SW PTD 100-238 From: Jim Re , Petroleum Engineer �P ` �4106 gg g Subject: Possible Injection above Confinement Mike Bill (BP; 564-4692) called 3/6/2006 to notify the Commission that, based on mechanical integrity logging, BP believes Prudhoe Bay well OWDW-SW may have injected out of zone. OWDW-SW is one of 3 Class I waste disposal injectors at Prudhoe Bay Pad 3 under EPA jurisdiction. Mr. Bill stated the well passed its annulus pressure mechanical integrity test (MIT) but early interpretation of the pulse neutron borax log run to detect fluid migration indicates there may have been injection out of zone. The log data indicates an anomaly at 1,800 feet (accumulation of borax); he noted the top of the confinement layer is 1,840 ft. BP and Schlumberger are still evaluating the log data. PBU OWDW-SW was left shut in and EPA has been notified. I asked him to copy us with anything sent to EPA that supports or denies the early log interpretation. ;a r 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska) Inc.( G}'v(, FIELD / UNIT / PAD: Prudhoe Bay / PBU f OWDW ` DATE: 03/03/06 OPERATOR REP: Mike Bill AOGCC REP: Packer Depth I Pretest Initial 15 Min. 30 Min. WelIJOWDW-NJ Type Inj. I N I TVD 1 1,900'1 Tubing 1 1001 1101 1201 120 Interval 1 P.T.D. 1002400 I Type test I P I Test psi 1 1,5001 IA 1 01 1,600 1,510 P/Fl P .1,5201 Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. Well OWDW-S Type Inj. I N I TVD 1 1,898-1 Tubing 1 4801 4801 480 480Interval 1 P.T.D.1002380 I Typetest I P I Test psi I 1,500 1 IA 1 101 1,6001 1,5501 1,550 P/Fl P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. Well OWDW-S Type Inj. I N I TVD 1 1,8851 Tubing 550 5501 550 5501 Interval 1 P.T.D. 1002390 I Type test I P I Test psi 1 1,5001 IA 0 1,6101 1,5301 1,520 P/F P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. Weill I Type Inj. TVD I Tubing I I I I Interval P.T.D. Type test Test psi IA P/F Notes: Weill I Type Inj. TVD I Tubing I I Interval P.T.D.1 Type test I Test psi I I IA I I I I P/F Notes: Test Details TYPE INJ Codes TYPE TEST Codes F = Fresh Water Inj M = Annulus Monitoring G = Gas Inj P = Standard Pressure Test S = Salt Water Inj R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2006-0303_MIT PBU_OWDW-SE.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) FAA 1 a 1 ; FRANK H. MURKOWSKI, GOVERNOR 9 ATASSA OIL AND GAS 333 W. 7" AVENUE, SUITE 100 � ANCHORAGE, ALASKA 99501-3539 CONSERVATION COM1 USSION PHONE (907) 279-1433 Bryan McLellan FAx (sol) 276-7542 Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay, OWDW-SW Sundry Number: 305-398 Dear Mr. McLellan: 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. Please provide at least twenty-four (24) hours 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. c:nairman DATED this day of January, 2006 Encl. V.Jcq 1-- ► [5`zoolo STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Suspend / ❑ Operation Shutdown ❑ Perforate ❑ Other ❑ Alter Casing ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Change Approved Program ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To D Number BP Exploration (Alaska) Inc.100-238 ❑ Development ❑Exploratory, ❑ Stratigraphic ® Service / 3.Address: 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21817-00-00 7. KB Elevation (ft): N/A 9. Well Name and Number: OWDW-SW � 8. Property Designation: 10. Field / Pool(s): ADL 028311 Prudhoe Bay Field 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 1 1 Effective Depth TVD (ft): Plugs (measured): Junk (measured): 2250 2250 2134 2134 N/A N/A Casinq Length Size MD TVD Burst Collapse Structural Conductor 100' 13-3/8" 100' 100' 4930 2670 Surface 2215' 5-1/2" 2215' 2215' 7740 6280 Intermediate ?-% — Production Liner r a t Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: �� C60 :u ng MD (ft): 1980'- 2005' 1980' - 2005' 2•a/6', 4.7a & 1-1/4•, 2.4n N-80 & J-55 fly 1140taft.-i Packers and SSSV Type: 5-1/2" Baker'DB' packer Packers and SSSV MD (ft): 18 ' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory [3 Development ®Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Janua 2 2006 ❑ Oil ❑ Gas ❑ Plugged ❑ Aba�doned [3 WAG ❑ GINJ ❑ WINJ ®WDSPL 16. Verbal Approval: D Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bryan McLellan, 564-5516 Printed Name Bryan McLellan Title Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5516 Date Terrie Hubble, 564-4628 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ❑ Plug Integrity [ 'BOP Test WtMechanical Integrity Test ❑ Location Clearance ec;� i CPE -'O 1750 PC . Othe Pte- 24o c 25.2 f5 oL tfe✓K-_fQ s t p gced th--e Ct ►L. e aj yut/e d . Subsequent Form Required: $ BFI.-- ,SAN 0 6 2006 -' ii� / APPROVED BY �r /. l �c)/�) THE COMMISSION ���" D6 Approved By: _ COMMISSIONER Date { rorm 1u-4u;J r+ewsea i/zu 5 /q,�/ � Submit In Duplicate ORIGINAL OWDW-SW proposed Rig Workover Procedure OWDW-SW is a Class I disposal well. The purpose of the proposed RWO is to replace the damaged tubing before communication develops between the tubing and Inner Annulus (IA). Proposed RWO procedure: 1. Prior to rig arrival, set a CT cement plug across perforations. Test plug to 1750 psi. Chemical cut the tubing above the production packer. 2. MIRU workover rig. Circulate kill weight fluid into tubing and IA. NU and test BOPE to 1750 psi (Note: wellhead equipment is rated to 2000 psi). 3. Pull and lay down 1-1/4" tubing string. 4. Pull and lay down 2-3/8" tubing to the cut. 5. Mill/fish packer. 6. RIH w/ casing scraper and clean out to below packer setting depth at +/-1900' md. 7. RIH w/ storm packer and set shallow in 5-1/2" casing. 8. Nipple down BOPE and remove tubing spool and spacer spool. Install new wellhead equipment. 9. Nipple up BOPE and pressure test BOP body to 1750 psi. 10. Pull storm packer. 11. RIH w/ mill and remove cement/fill to bottom perf. 12. RIH w/ and set production packer. / 13. RIH w/ new 2-7/8" L-80 tubing. Completion will have control lines run to 500' to circulate a nitrogen cushion into the IA. 14. Displace IA to packer fluid, freeze protect tbg & IA, and stab into seal bore on packer. 15. Test tubing to 1750 psi. Test Inner Annulus (IA) to 1750 psi. 16. Set TWC. ND BOPE. NU and test tree. Pull TWC. Set BPV. RDMO. 17. Pull TTP with slickline. 18. Reperf cemented interval if necessary and return well to Class I disposal service. �9 WELLHEAD = ACTUATOR = KB. REV= 56.5' BF. REV__ KOP = p Max Angle = 0 Datum MD Datum TVD = 13-3/8" CSG, 72#, N-80, ID = 12.347" 1 100' 1 Minimum ID =1.822" @ 1916' BAKER R NIPPLE 1-1/4" TBG, 2.4#, J-55,.00185 bpf, ID = 1.380" 1-i 1865' OWDW-SWSAFETY NOTES: SOME LOGS ARE MEASURED EXISTING COMPLETION ROM GROUND LEVEL. NITROGEN BLANKET IN 2-3/8" TBG, 4.7#, N-80,.00387 bpf, ID = 1.995" 1-1 1918' PERFORATION SUMMARY REF LOG: DIL ON 06/25/73 ANGLE AT TOP PERF: 0 @ 1980' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 1980-2005 O 01/02/85 PBTDI—I 2134' 5-1/2" CSG, 17#, L-80, ID = 4.892" 2215' TD 2250' 1898' I -I BAKER DB PKR 1916' 1-12-3/8" BAKER R NIP, ID = 1.822" 1917' –1 2-3/8" WLEG 1918 ELMD TT LOGGED 03/24/85 DATE REV BY COMMENTS DATE I REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 01/01/85 RWO 03/03/01 SIS -MD FINAL 09/19/01 RN/KAK CORRECTIONS 09/27/01 MB/KAK I CORRECTIONS PRUDHOE BAY UNIT WELL: OWDW-SW PERMIT No: 00-238 API No: 50-029-21817-00 SEC 11, TION, R14E, 1064 FEL, 668 FNL BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = KB. R EV = 56.5' OWDW-SW PROPOSED COMPLETION IRAFETY NOTES: SOME LOGS ARE MEASURED FROM GROUND LEVEL. NITROGEN BLANKET IN DATE REV BY COMMENTS DATE I REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 12/27/05 BJM PROPOSED RWO 01/01/85 RWO 03/03/01 SIS -MD FINAL 09/19/01 RN/KAK CORRECTIONS 09/27/01 MB/KAK CORRECTIONS PRUDHOE BAY UNIT WELL: OWDW-SW PERMIT No: 00-238 API No: 50-029-21817-00 SEC 11, T1 ON, R1 4E, 1064 FEL, 668 FNL BP Exploration (Alaska) Re: OWDW-NW and OWDW-SW Sundry Ocation variance... Subject: Re: OWDW-NW and OWDW-SW Sundry Application variance request From: Winton Aubert <winton aubert@ad min. state.ak.us> Date: Thu, 05 Jan 2006 07:29:59 -0900 To: "McLellan, Aryan X <Bryan.McLellan@bp.com> Bryan, FYI, the regulatory citations that apply to workover operations as described below are 20 AAC 25.285 (f) (1) and 20 AAC 25.285 (c) (2). Per 20 AAC 25.285 (h), alternate BOPE and alternate BOPE test procedure are approved for workover operations on wells OWDW - SW (Sundry No. 305-398) and OWDW - NW (Sundry No. 305-399). Winton Aubert AOGCC 793-1231 McLellan, Bryan J wrote: Winton, As we discussed on the phone, BP would like to request a variance from the AOGCC regulation 10 AAC 25.035(e)(1 0)(A) for Rig Workover operations on wells OWDW-NW and OWDW-SW. The variance request is specifically for step #9 of the attached "Scope of Work" documents that were sent to the AOGCC on 12/29/05. In step #9, the BOP's will be nippled back up on the wellhead after being temporarily removed in order to replace a tubing spool. The BOP's will receive only a body pressure test (to test the flange connection on top of the new tubing spool), instead of pressure testing each BOP component as required in the AOGCC regulations. The BOP's will have been fully pressure tested in accordance with AOGCC regulations —2-6 days prior to this operation, when they were initially installed on the,well. Additionally, BP would like to request a variance from regulation 10 AAC 25.035(e)(1)(A)(i) for Rig Workover operations on the above mentioned wells. The RWO scope (step # 3) includes removing —1860 ft of 1-1/4" CS Hydril tubing (1.660" OD) from the well. This is an unusual tubing size and BP has had difficulty locating pipe rams that will fit. BP is proposing to pull this tubing without pipe rams that will close around it. To mitigate any risk associated with this operation, the perforations will be fully cemented and pressure tested prior to rig arrival. Kill weight fluid will be circulated inside the tubing and inner annulus in the well prior to pulling the tubing. The BOP stack will be fitted with blind/shear rams and an annular as a contingency. <<OWDW-SW RWO Scope of Work.doc>> <<OWDW-NW RWO Scope of Work.doc» Please feel free to call if you would like to discuss either of these requests Thank you, Bryan McLellan RWO Engineer BP Exploration, Alaska 564-5516 1 of 1 1/5/2006 7:31 AM Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wpll .Inh # NO. 3460 1 o 0 w3 9 Company: State of Alaska Alaska Oil & Gas Cons Comm ` a EP = L Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay I nn npccrintinn nate RI rnlnr rn 08/30/05 Z-15 /33-- MY 11084273 PPROF W/DEFTIGHOST/CALIPER 07/08/05 1 1-5-17A X,.3 11075898 MEM PPROF W/DEFT/GHOST 07/03/05 1 DS 04-26 j / 11072873 PRODUCTION PROFILE 07/30/05 1 S -14A 10893047 LEAK DETECTION LOG 10/17/04 1 G-27 A - ' W 10942221 MEM PPROF & IPROF 06/29/05 1 DS 05-20B 10942220 MEM INJECTION LOG 06/26/05 1 E -37A v ` - GC ti 10928640 MEM PPROF, IPROF & WARMBACK 06114/05 1 D-29 j� r- .3 11084274 RST 07109/05 iA,22 1-2-28 /�S s� - �% 3 S - 11076453 RST 07/27105 1 1 % 3;t ` C -13A 11075900 MCNL 07/05/05 1 1 % .Lls- OWDW-SW/ li - ,�3 Y 10893096 RST -BORAX CHANNEL DETECTION LOG 03/24/05 06-08A 19 -- j 11062628 RST 05/17/05 1 1 3 A27 12-29 y - �. '2- 11072867 RST 07/07/05 1 1 32.4-8 C -19B C'� - Q► ��. 10928632 MCNL 05/12/05 1 1 13 G-27 �� (S U 10942221 MCNL 06/29/05 F -02A ,� V ' C' ( 10928630 MCNL 05/08/05 03-33B IQ y - 1 10913011 USIT PDC -GR 03/19/05 1 1 op). ,. MPK-22 10893106 USIT 04/20105 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center 1.132-1 900 E. Benson Blvd. Anchorage, Alaska 99508 9. Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950.3-2838 ATTN: Beth f_ Received by:�-- d ou_zr,c STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / OWDW 0 r 03/27/05 1 Rob Mielke Packer De th Pretest Initial 15 Min. 30 Min. F = Fresh Water Inj M = Annulus Monitoring Well OWDW-N Type In'. N TVD 1 1,880' Tubingl 5901 5901 5901 5901 Interval O P.T.D. 100-240 1 Type test P Test psi 1 1,500 Casingl 1001 1,5501 1,4551 1,425 P/FJ P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. AOGCC re resentative declined to witness test. Weill OWDW-S Type In'. I N I TVD 1 1,898'1 Tubingl 4801 4801 4801 4801 Interval O P.T.D. 00-25 — I Typetest I P I Test psi 1 1,5001 Casingl 101 1,5501 1,4801 1,465 P/FJ P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. AOGCC re resentative declined to witness test. Well OWDW-SE -Type In'. I N I TVD 1 1,885'1 Tubingl 1301 1301 1301 1301 Interval O P.T.D. 100-239 I Type test I P I Test psi 1 1,5001 Casingl 21 1,5501 1,4801 1,460 P/F I P Notes: EPA required annual pressure test. Witnessed by EPA representative Talib Syed. AOGCC re resentative declined to witness test. Well I I Type In'. I I TVD I I Tubingl I I I I Interval P.T.D.1 Type test I I Test psi I I Casin P/F Notes: Well Type In'. I TVD I I Tubingi I I I I Interval P.7.D.1 I Type test I I Test psi I I Casing P/F Notes: Test Details: TYPE INJ Codes TYPE TEST Codes F = Fresh Water Inj M = Annulus Monitoring G = Gas Inj P = Standard Pressure Test S = Salt Water Inj R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 MIT PBU OWDW-NW, OWDW-SE, & OWDW-SW 03-27-05.xis INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) ? of'Q awly IM -a 20-63' 701-tio `O`I-lo7 2�Dit�0<< -Ctf 0 -0 11/23104 Schlumberger NO. 3277 CH EDIT PDC -GR 09/02/04 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 OWDW-SW Anchorage, AK 99501 RST -SIGMA Field: Prudhoe Bay Color Wall Inh # Lnn DPcrrintinn Date RinplinP Prints CD W -05A 10715426 CH EDIT PDC -GR 09/02/04 1 1-3-02 10708048 RST -SIGMA 02/05/04 1 1 OWDW-SW 10563038 RST -SIGMA 03/30/03 1 1 OWDW-SW 10672360 RST -BORAX 03/27/04 1 1 P1 -07A 10621778 USIT PDC 04/20/04 1 1 J -25A 10715419 MCNL 08/13/04 1 1 C -25B 10715434 MCNL 10/11/04 1 1 S -14A 10884020 MCNL 09/18/04 1 1 E -39A 10728394 MCNL 03/28/04 1 1 07-32B 10861926 MCNL 08/03/04 1 1 Q -05A 10715356 MCNL 10/26/03 1 1 DS 09-41 10563111 RST -SIGMA 10/12/03 1 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. Anchorage, Alaska 99508 �! �i SL SPI � 2005 Date Delivered: ���__' i Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950 838 ATTN: Beth Re ived by: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay/ PBU / OWDW 03/26/04 Roland Johnson /Anna Dube Well OWDW-S Type In'. F Packer Depth I TVD 1 1,898'l Pretest Tubin 6601 Initial 15 Min. 30 Min. 6601 6601 6601 Interval o P.T.D.00-238 I Type test P Test psi 1 1,5001 Casingl 1,4551 1,5001 1,4751 1,465 P/Fl P Notes: Annual EPA Witnessed Test - AOGCC declined witnessing T = Test during Workover Weill Type In'. I I TVD I I Tubin Interval P.T.D. Type test I Test psi I I Casin P/F Notes: Weill Type In'. I I TVD I ITubingi I Interval P.T.D. Type test I I Test psi I I Casing P/F Notes: Weill Type In'. I TVD I I Tubingl Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type In'. TVD I Tubingl I Interval P.T.D.1 Type test I I Test psi I I Casin P/F Notes: Test Details: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = Standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover D = Differential Temperature Test O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU OWDWSW 03-26-04-1.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim _eggs min. tate.ak.us OPERATOR: BP Exploration (Alaska) Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / OWDW DATE: 03/28/03 OPERATOR REP: Anna Dube AOGCC REP: John Spaulding - AOGCC, Thor Cutler - USEPA, Talib Syed - EPA consultant Packer Depths (ft.) I TYPE TEST Codes Pretest Initial 15 Min. 30 Min. S =Salt Water Inj R = Internal Radioactive Tracer Survey 'Nell OWDW NW I Type Inj. I N MDrrVD I 1,880' 1,880' Tubing 5601 5601 5601 5601 Interval 1 P. T.D. 1002400 I Type test I P Test psi 1 15001 Casingl 01 15001 14101 13801 PIFI P Notes: Class 1 Injection Well Permit AK - 11004 A 'Nell OWDW-SW I Type Inj. I N I MD/TVD 1,898' 1,898'1 Tubingl 4801 4801 4801 4801 Interval 1 P.T.D. 100238 I Type test I P I Test psi 1 15001 1 Casingi 601 15301 15001 1490 P/171 P Notes: Class 1 Injection Well Permit AK- 11004-A Well OWDW SE I Type Inj. I N I MDr VD 1,885' 1,885-1 Tubingl 4601 4601 4401 440Interval 1 P.T.D. 1002390 I Type test P Test psil 1500 Casingi 401 15001 14201 1410 P/F P Notes: Class 1 Injection Well Permit AK- 11004-A Weill Type Inj. MD1TVDI I I Tubingl I I I IInterval P.T:D. Type test Test psilCasin P/F Notes: Welll IType Inj. MD/TVD1 I I Tubingi inte!P/FJ P.T.D. Type test Test psi Casin Nates: Test Details: OW'DW-NW Pumped 3 bbls of diesel down the IA. Well was shut in on 03-27-03 at 18:00 PM. OIA'DW-SW Pumped 1 bbl of diesel down the IA. Well was shut in on 03-27-03 at 13:00 PM. OWDW-SE Pumped 1 bbl, of diesel down the IA. Well was shut in on 03-19-03 at 01:00 AM. TYPE INJ Codes TYPE TEST Codes F = Fresh Water Inj M = Annulus Monitoring G = Gas Inj P = Standard Pressure Test S =Salt Water Inj R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey D = Ditferential Temperature Test MIT Report Form Revised: 06/19/02 MIT PBU OWDW 03-28-031.xis INTERVAL Codes 1= Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) Schlumber er GeoQuest 3; 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN-. Sherrie { 5 Well Job # Log Description NO. 10223 Company: Alaska Oil &Cas Curtis Comm Attn: Howard Oakland 3001 Porcupin-- Drive Anchorage, AK 99501 Field: Prudhoe Bay Date BL OWDW-SE ✓ OWDW-NW TEMPERATURE OVERLAY PUMP -IN TEMPERATURE SURVEY 960429 1 960430 1 OWDW-SW PUMP -IN TEMPERATURE SURVEY 960430 1 D.S.' 7-03A PRODUCTION PROFILE LOG 960503 1 D.S, 7-03A DUAL BURST TDT-P 960504 1 D.S. 11-26 PERFORATING RECORD 960425 1 D.S. 14-03 PERFORATING DEPTH CONTROL 951108 1 b.S. 14-17 INFLATABLE BRIDGE PLUG 951108 1 D.S. 15-14 TUBING PATCH RECORD 951120 1 D -S. 15-15 ✓ PERFORATING RECORD 951123 1 U.S.—, 5 - 1 - 6 TUBING PATCH RECORD 951117 1 D.S. 15-39 ✓ TDT P BORAX LOG 960429 1 D.S. 16-5 V PERFORATION RECORD 951111 1 D.S. 16-10 PERFORATION RECORD 951112 1 D.S. 18-34 TDT P BORAX LOG '960428 1 Anadriii RF Sepia Survey Calculation f f p .- 4! 1° SIGNED:UW CJ 1 Please sign and return one opy of this trionsmittal to Sherrie at the above address. Thank you. It (r ' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Anadrill Program DATE.:',..-�-- 6/4/96 Anadrill Performance Letter. ALASKA INDIVIDUAL WELL PRODUCTION AS OF 10/23/96 1992 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 9 16 24 24 28 29 27 23 30 12 8 15 OIL WTR 2,598 7,892 19,564 29,180 19,961 28,435 20,515 12,746 20,164 5,721 3,158 3,314 GAS 1992 TOTALS OIL WATER 173,248 GAS CUM OIL CUM WATER 1,833,657 CUM GAS 1993 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 2 11 30 25 31 30 30 30 29 29 28 26 OIL WTR 306 6,225 19,249 11,456 24,715 36,806 13,184 16,784 10,092 12,171 13,873 13,467 GAS 1993 TOTALS OIL WATER 178,328 GAS CUM OIL CUM WATER 2,011,985 CUM GAS 1994 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 30 28 31 27 31 28 25 28 29 27 27 21 OIL WTR 17,286 12,417 12,247 10,626 20,286 62,073 16,868 24,741 16,785 12,538 7,273 7,987 GAS 1994 TOTALS OIL WATER 221,127 GAS CUM OIL CUM WATER 2,233,112 CUM GAS 1995 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 17 5 17 23 28 29 30 29 29 29 25 22 OIL WTR 3,270 1,533 8,913 5,408 17,295 47,760 13,587 48,637 100,751 11,820 7,654 20,312 GAS 1995 TOTALS OIL WATER 286,940 GAS CUM OIL CUM WATER 2,520,052 CUM GAS 1996 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 30 23 22 29 31 30 31 31 OIL WTR 15,536 7,029 11,409 15,883 36,152 48,260 18,283 34,203` GAS 1996 TOTALS OIL WATER 186,755 GAS CUM OIL CUM WATER 2,706,807 CUM GAS f 3 RCO Alaska, Inc. - Prudhoe r v Well : OWDW - SW SDI =: 50-029-21817-00 ``` Type: Oily Waste Di. Spud Date: 6/-'71'S'/73 Como_etion:1/1/85 Status:Workover Original RKBE: :anger Type: FMC Dual :.anger: lop of Fo=a-tion : 0' -Max -ole Angle: ° @ Y : 0' :angle @ TS: Annular F1uid:Glycol Angle @ TD: Reference Log: Date: 00/00/00 Tie I._. Dater 00/00/00 NOTE: All depths are referenced from ground level =0' to top of equipment. ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. C) 2"s % Casing and Tubing (C) Size Weight Jewelry (J) Top Bottom Description 1 13-3/8" -2# N-80 0' 100' Depth Description 2 5-1/2" .7# N-80 0' 2215' Cas: :g 2-3/8" =.7# 1 1898' __{er DB Packer 0' 1918' T1;:_=zc 1-1/4" _.4# J-55 0' 1865' 2 1916'-3/8" Baker R Nipple =_=1.822" Perforation Data (ELM DEPTHS) (P) J-1 -Interval Zone 3 1917' ..-3/8" W/L Re-entry Gui;:e Date Comments 1 1980- 2225 25 4 01/02/85 4 1918' 2-3/8" Tubing Tail J-2 Datum 1918' --.�i Tubing Tail (Logged 03/24/85) Revision Date: 05/22/93 by PTB 8700' SS= ND PBTD= 2134' Reason: 4D Z�NV=RSION C-1 TD= 2215' Previc::s Re_son: 05/03/91 Min ID: 2-3/8" Baker R Nipple ID=1.822" C) 2"s % Casing and Tubing (C) Size Weight Grade Top Bottom Description 1 13-3/8" -2# N-80 0' 100' Cas_�y 2 5-1/2" .7# N-80 0' 2215' Cas: :g 2-3/8" =.7# N-80 0' 1918' T1;:_=zc 1-1/4" _.4# J-55 0' 1865' Tu_i-Aa Perforation Data (ELM DEPTHS) (P) J-1 -Interval Zone FT SPF Date Comments 1 1980- 2225 25 4 01/02/85 ___TRF J-2 Datum Revision Date: 05/22/93 by PTB 8700' SS= ND PBTD= 2134' Reason: 4D Z�NV=RSION J-3,4 8800' SS= :' ND TD= 2215' Previc::s Re_son: 05/03/91 P-1 C-2 Well OWDW-SW RECEIVED APR 0 5 1996 ^_'ska Oii & Gas Cons. Commission Anchorage { Distribution: The Abo%e is Correct: t� Ori;.: Drilling Section - Dallas ee:• District office 4 Enpineerin£ Division . (720) Sit.%ARrt pan Co -O ofter(s) - An Aprrcprsst. DIc�ICT DRILLING Stt:'EPVISOR Regional Office, 'hell llecerd File �Ati= r0.���fNt'rlt/n ALL OtaLT SELL NttTORT TMw#* aMISKLM111 ti TUT a1K ncraNEo no Lao BELL.1 38-439•1 ' M h /►�t�r� r%►.tt the 1411T14L Frpo" •• the ft►tt 964409det •f fell f• •podded or •orie•er •f4rottos• •rr • •t�rt�t. •tit • 11 0.401 to Apeddt&I •40616 be 64668a184d *0 %be Iorit petbs 6861686.9 40418 •*1t. DAILY WELL HISTORY -INITIAL REPORT District • NORTH DISTRICT Count, or Parish NORTH SLOPE State ALASKA • Field PRUDHOE SAY 4 S G✓ Lease or trait Nett 10._ Auth. or M .O. �o. 0203- Title=='s.'" _S^ �'; o._J'r"^ COL +'-s- :�• V— - Operator -�...__�D :..._�..�. T.+ARCO'S w.I. 50 Spudded or p.0. Begun Prior Status e_�a Date -2--"3 Hour2:00 X.1' if a w. 0. Date d Depth e:00 A.1(. Complete Record for each Day Reported as of 6-25-73 rc^''.AEr3ST TEST P7: T'? S��V7X'':5T ::::.L =4 - NORTH SLOPE -I _1 1793' 1793' (1793' ) - Ori i ng - '•t11 y. 5#, Vis 300. (Cum 20) Moved b RU. Scud 2:00 Aft 6-24-73. Mud temp in 41", out 55°. Survey: 138 bullseye. 6-26-73 PERMAFROST TEST PROJECT SOUTHIEST WELL #4 - NORTH SLOPE 2250' 2250' (457') - Running 5-1/2" csg - MW 9.3#, Vis 300. (Cum 21) Ran DIL 2225 to surface. Ran 4 -arm caliper from 2225 to surface. Have 44 j is 5-1/2" csg in hole @ 6 AM. Survey: 2250' n.g. { Distribution: The Abo%e is Correct: t� Ori;.: Drilling Section - Dallas ee:• District office 4 Enpineerin£ Division . (720) Sit.%ARrt pan Co -O ofter(s) - An Aprrcprsst. DIc�ICT DRILLING Stt:'EPVISOR Regional Office, 'hell llecerd File �Ati= r0.���fNt'rlt/n ALL OtaLT SELL NttTORT TMw#* aMISKLM111 ti TUT a1K ncraNEo no Lao BELL.1 38-439•1 • VCTIC"S! *roost* • •►sit the FINAL REPORT as t►• fist gsdsssdsl •fist, •oblo tss leas 60610604 of slid 1• pledged. eslneed. or Sold. Firk :PONT •►mold be sa►s&tt@d silo sbss sPetotaess &ra o�sdsd for ss udofio&te of approoloblo 10660 61 1600. Os sur►�....+a @bel as eff6s&al tont is sot required up* s e@sPlaties. ►@Port e0401e1606 sN ►@Presestst&ve so@$ dots is ►lee►a Provided. The FINAL MOST lets se? be used lot #*parties tb@ sett#• •Perot&@& $I •Pose to available. DAILY WELL HISTORY - FINAL REPORT District' NORTH DISTRICT County or Parish NORTH SLOPE State ALASKA Field_ PRUDHOE BAY Lease or Unit WeII 21o. 4 I9293iCT SOL -:5 LLLAuth. or 1%001640%e " a ( It;FODM4' 7 0? 0.'1L': ) Operator ATL41MC RICF-F1=,D CObi°AYY r TARCO-S W.1. SO Spudded or Spud 6-21-T3 - 2.00 Prior Status N.O. Begun Date Hour if a W.O. Date & Depth as of 8:00.A.M. Complete Record for Each Day Reported 6-27-73 PERMAFROST TEST PROJECT SOUTHWEST WELL f4 - NORTH SLOPE (5-1/2" 0 2215') 2250'TD 22501TO - Ran 56 jts 5-1/2" 17f Mod N-80 butt csg w/shoe A 2215', float (Cum 22) collar @ 2134'. Ran cable #5 to 1797'. Circ cmt to surface w/3670 sx Dowell Arcticset w/10#/sack Kolite b .1: D-13. Pump plug down w/water. Displaced cmt w/water to 80' in 13-3/8" x 5-1/2" annulus. Raised SOPE b threaded cable thru side outlet of wellhead. Recemented top 80' of 13-3/8" x 5-1/2" annulus w/120 sx Arcticset. CIP 3:10 PM 6-26-73. Landed csg. Ran 2-3/8" tbg to 2134'. Displaced 5-1csg w g yco . POH. RR 8:00 PM 6-26-73. RECEIVED _ APR 0*5 1996 At- ,Ska Oil & Gas Cons. Commission Anchorage Old -TD New TD PB Depth Reltissed Rig 8:00 Fm Date 6-26'73 Kind of Ain Classifications Type Completion (Oil, Gas, etc.) (Single, Dual, etc.) N Producing•Mathod Official Reservoir Name(s) _D..._...:.i T-.# n.v.• C • DATE • 11LSEAVOIN M. WELL No. • DATE • 11LSEAVOIN ►0100110NG IXTENVAL OIC TEST Tutt PrOOCCTION OIL ON TEST GLS PEA OAT ?UvP SIZE. SPIN I LEXCM CNOKE silt T. P. C. P. WATER I GOR GRAWITT CORRECTED ALLOWABLE EFTECTtvt DATE Lliatributson: Ike Above is •t-orrect: Orifi.: Drilling Section . Dallas i / • cc: • District Office gl d - ----� Z/' ?3 Engineering Division - (720) SIGMIL" DATE Co -Owners) • As Appropriate 12.r. DISTRICT DRILLING SUPt'RVISOR Regional Office, Nell Record File TITU PALL No.� 2 �cl UMI& ALL 9411.1 6ELL NISTDAT FOAaS CONiICUTIT LT AS TUT AMC MKPANG MR EAU WELL. • Is•ds�a • futon use AtlanticRichfiel%, mpany Drilling—Col letion—Workover Log Q 4iw r Mw wooa•r•tw '��— salsa Thav h Subsidence Test Pad 3 S.W. Iowa pNwa Wa � /If1f OMYM Nowa ar/M �� hvdhoe Bar N. Alaska l Taw N uw M par•M 7;� Time dk*4O ". h"ft Do" so e•NM Allli•t�11 ' Borth Slope Alaska !mormo.. To ranw Rig up ane tear #own 1 t Ran 64 its + pup j 2-3/8" buttress used. 6a is 198 artt ne.rt•.t pup 3.50, total 1989.0+. Landed v/vrao around donut. Made Onaet.owat � dMIAq I u2 hold dove studs, flanged up, hooked up flow line. ""~V Trope U Changs, ON 1 t t Orl"Ov wom f j penal returns t 1989. total tubing ng m+ i Cow-bC;; ng 1 Conwtan.nonwe � and c1mostin3 swt•�ns ' i pwr•at•on w•na�r • l,raiCw. rM _ QA on Ow Aapaf of +� Taw or B.O.F. � swe woo O.m•sM rkv aw OrW sr.m we O"m how I / wwa 1ma ' booms even j and ea•nN•er•q wa•t•n4 r+ ea••aw Cased babe IN+orwno w•raw AM woo •wr ea"e t•e•e Ono soave ww ewe be" 'to"" s..araq \ AaWms F ache" • Twy Ww Talala j9*A few TrNpM Grab rp~ CUM am O.D. 6"" tti.a w ma w* -- salsa ON gem Iowa pNwa Wa c-~ Nowa ar/M Jswa Owe taws awn" l Taw Ar M Do" so e•NM Allli•t�11 Tow eve owe G.C�M is.� A14ASKA OIL AND GAS CONSERVATION COMNYISSION May 15, 1996 i TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 =AX: (907) 2-6-7542 Grover Partee, Env Engr US EPA Region 10 WD133 1200 Sixth Av Seattle, WA 98101 Re: Alaska Class II Facilities Second FFY96 Report: 10/01/95 - 03/31/96 Dear Mr. Partee: Enclosed are appropriate EPA forms 7520-1, -2A, -26, -3, and -4 covering UIC Class II facilities in the State of Alaska for the period October 1. 1995 through March 31, 1996. Also enclosed are the records for the 'MITs conducted on the three Class 1 wells at ARCO's PBU DS 6, Pad 3. If you have any questions, please call me at (907) 279-1433 Sincerely, Blair E Wondzel E. Project Manager Ijb/encls A:18EW1uicVaci1rpt OPERATOR: Arco Alaska Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test FIELD / UNIT / PAD: Prudhoe Bay / PBU / Pad 3 DATE: 4/29/96 OWDW O Glycol 1,898 560 540 540 540 S• W N COMMENTS: 1, 898 5 1/2" / 17# / N-80 2 3/8" 1500 1 0 1, 820 1, 750 1,730 1 9:45 AM X OWDW N.W. O I W N Glycol 1880 5 1/2" / 17# / N-80 2 3/8" 1500 760 760 750 740 10:40 AM X 1880 40 1 1860 1 1800 1780 COMMENTS: 0 COMMENTS: nr"1RA�AC1►ITQ. 0 *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING Distribution: orig - Well File c - Operator c - Database G - Trip Rpt File c NInspector ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 0.00 0.00 0.00 WELL TEST": Initial 4 - Year Workover� Other Annual AOGCC REP SIGNATURE OPERATOR REP SIGNATURE JG9HD2DD.XLS F1--%5'1 (Rev. 3/93) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto DATE: April 29, 1996 Chairman TSRU: Blair Wondze, FILE NO: jg9hd2dd.doc P. I. Supervisor 06 FROM: Doug Amos, SUBJECT: Mech. Integrity Test Petroleum Inspector Arco PBU Pad 3 Prudhoe Oil Pool Monday, April 29, 1996: 1 traveled to Arco's PBU DS -6 Pad 3 to witness the Annual Mech. Integrity Test on the 3 Oily Waste Disposal Well. As the attached AOGCC Mech. Integrity Test Form indicates all three wells were successfully tested in accordance with all applicable AOGCC regulation and Area Injection Orders. SUMMARY: I witnessed the successful Mech. Integrity Test on Arco's PBU Pad 3 Oily Waste Disposal Wells. Attachment: JG9HD2DD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo , Chairman THRU: Blair Wondzell, ,6X4v-;� P. 1. Supervisor 514111 FROM: Bobby Foster Petroleum Inspector DATE: April 29, 1995, 1995 FILE NO: JG91D3CD.doc SUBJECT: Mechanical Integrity Test ARCO -PBU-Pad 3 Prudhoe Bay Field Saturday, April 29, 1995:_1 traveled this date to ARCO's Pad 3 and witnessed the MIT's on the oily water injection wells OWDW - SW, OWDW - SE, OWDW - NW. As the attached AOGCC Mechanical Integrity Test Report shows all 3 wells met the regulations set forth in 20 AAC 25.412 concerning undergound injection. Summary: I witnessed the satisfactory MIT's on the above listed wells. Attachment: JG91D3CD.XLS OPERATOR: ARCO ALASKA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test FIELD / UNIT / PAD: PBF -PBU - PAD 3 DATE: 4/29/95 *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING OW = OILY WASTE Distribution: odg - Well File c - Operator c - Database c - Trip Rpt File c - Inspector ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 6.83 0.35 0.00 0.00 0.00 WELL TEST: Initial 4 - Year x Workover Other AOGCC REP SIGNATURE BOBBY D. FOSTER OPERATOR REP SIGNATURE RICHARD ORTEIZ JG91D3CD.XLS FI -051 (Rev. 3/93) HE 'B 4"U TV I %YM z! 5 r wry R R P $ is -T E& -.10P NN -11 4=4�;TEST 17M 411 G PRESSSS iit OWDW SW O W N GLYCOL 1,898 5.5 17# N-80 2.374 1,500 560 560 550 550 9:25AM P 1,898, 0 1,780 1,700 1,680 COMMENTS: Pretest pressure was observed for 30 minutes prior to test. OWDW - NW 0 W I N 1 GLYCOL 1 1,8800 5.5" - 17# - N-80 1 2.375"1 1,500 475 430 430 430I 10:10AM P 1,8801 1 0 2,190 2,050 2. 000 d COMMENTS: Pretest pressure was observed for 30 minutes prior to test. OWDW - SE 0 I W 1 N GYLCOL 1,88 5.5'1 - 17# - N-80 2.3761-1 1 1,500 150 150 150 150 9:50AM P 1,8890', 0 1 1,760 1 1,710 1 1,690 COMMENTS: Pretest pressure was observed for 30 minutes prior to test. 0, COMMENTS: COMMENTS: *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING OW = OILY WASTE Distribution: odg - Well File c - Operator c - Database c - Trip Rpt File c - Inspector ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 6.83 0.35 0.00 0.00 0.00 WELL TEST: Initial 4 - Year x Workover Other AOGCC REP SIGNATURE BOBBY D. FOSTER OPERATOR REP SIGNATURE RICHARD ORTEIZ JG91D3CD.XLS FI -051 (Rev. 3/93) 'C. Alaska, Inc. - Prudhoe Well:OWDW-SW API #:50-029-21817-00 Type:Oily Waste Di. Spud Date: 6/24/73 Completion:1/1/85 Status:Workover Original RKBE: Hanger Type:FMC Dual Hanger: :op of Formation: 0' Max Hole Angle:° @ MD: 0' Angle @ TS: Annular F1uid:Glycol Angle @ TD: Reference Log: Date:00/00/00 Tie In: Date: 00/00/00 NOTE: All depths are referenced from ground level =0' to top of equipment. ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry (J) Depth Description 1 1898' Baker DB Packer 2 1916' 2-3/81' Baker R Nipple ID=1.822" 3 1917' 2-3/8" W/L Re-entry Guide 4 1918' 2-3/8" Tubing Tail 1918' ELM Tubing Tail'(Logged 03/24/85) C-1 Min ID: 2-3/8" Baker R Nipple ID=1.822" Casing and Tubing (C) Size weight Grade Top Bottom Description 1 .13-3/8" 72# N-80 0' 100' Casing 2 5-1/2" 17# N-80 0' 2215' Casing 2-3/8" 4.7# N-80 0' 1918' Tubing 1-1/4" 2.4# J-55 0' 1865' Tubing La Perforation Data (ELM DEPTHS) (P) J-1 Interval Zone FT SPF Date Comments 1 1980- 2005 25 4 01/02/85 IPERF J-2 Datum Revision Date: 05/22/93 by PTB 8700' SS= 0' MD PBTD= 2134' Reason: 4D CONVERSION J-314 8800' SS= 0' MD TD= 2215' Previous Reason: 05/03/91 P-1 Well OWDW-SW C-2 . ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, : )` .orage, AK 99510' March 24, 1995 Transmittal #: OWDW Data, 1 Blueline, 1 Film Karla Zuspan/ATO-1515D 265-6547 Bob Crandall, AOGCC RECEIVED MAR 2 0 1995 Alaska Oil & Gas Cans, Commission Anchorage Please retain one copy and return a signed copy as receipt of data. 00-)LqA 00-),14( 00 -;,4o Oce -;L 3q 00 - X$e Well Number Log Date (M -D -Y) Tool Type Contractor OWDW-C 06-20-73 DIL Sch 06-20-73 BHC Sonic Sch 06-20-73 Comp Fm Den G R, Sch 06-20-73 Comp Neut GR Sch 06-21-73 4 -Arm Caliper Sch -NE 06-16-73 DIL Sch 08-01-73 GR Neutron Sch 06-16-73 4 -Arm Caliper Sch -NW 06-08-73 4 -Arm Caliper Sch 06-08-73 DIL Sch 07-31-73 GR Neutron Sch -SE 06-29-73 4 -Arm Cali erg Sch 06-29-73 DIL v' Sch -SW 06-25-73 DIL Sch 06-25-73 4 -Arm Caliper Sch Number of Records: 15 ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfleldCompany I" nA[[ r Lru /Al A11.ASIiA 01114AND GAS � CONSERVt1TI011i COMI►IISSI011T May 9, 1995 Grover Partee, Env Engr US EPA Region 10 WD133 1200 Sixth Av Seattle, WA 98101 Re: Alaska Class II Facilities Second FFY95 Activity Report Dear Mr Partee: TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Enclosed are appropriate EPA forms 7520-1, -2A, -213, -3, and -4 covering UIC Class II facilities in the State of Alaska for the period October 1, 1994 through March 31, 1995. Also enclosed is a report of MITs on the three Pad -3 disposal wells operated by ARCO in the Prudhoe Bay Field. If you have any questions, please call me at (907) 279-1433. Sincerely, Blair E Wondz I, P.E. Project Manager encls COMMENTS: (OILY WASTE DISPOSAL WELL) COMMENTS: *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING D=DISPOSAL Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 6.8 0.35 DATE: th>tnt : � IMllM ; TIME ;.TIME STATE OF ALASKA TBG . TRESS PRESS' ALASKA OIL AND GAS CONSERVATION COMMISSION 1.450 1.430 Mechanical Integrity Test OPERATOR: ARCO FIELD I UNIT I PAD: PRUDHOE BAY/PBU/PAD - 3 PRETEST* ... �. P '�I Tlf ;PACKER :REG. TIME WELL° *S :..;;ANNULUS TVD :. :CASING: TBG :TEST ,TBG :CSG TBG N `: FLUID 77 a D SIZE 1 illl'F /GRADE SIZE PRES. PRESS CSG .:: . . OWDW-SE N DIESEL 1885' 13-3/8" / 72# / N-80 2-3/8" 1,500 140 140 D I 1 1 1885' 5-1/2" / 17# /N-80 10 1,500 COMMENTS: (OILY WASTE DISPOSAL WELL) OWDW-SW * Nt DIESEL 1898' 4 13-318" / 72# / N-80 2-3/8" . 1500 640 640 D 1 1898' 5-1/2" / 17# / N-80 10 1,980 COMMENTS: (OILY WASTE DISPOSAL WELL) - OWDW-NW I t N DIESEL 1880' 13-3/8" / 72# / N-80 2-318" 1500 1 520 525 D 1880' 5-1/2" / 17# / N-80 20 1 2030 COMMENTS: (OILY WASTE DISPOSAL WELL) COMMENTS: *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING D=DISPOSAL Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 6.8 0.35 DATE: th>tnt : � IMllM ; TIME ;.TIME TBG TBG . TRESS PRESS' 140 140 1.450 1.430 640 630 1.930 1.910 525 525 1980 196( 4/29/94 11:OOAM P 8:30AM P 10:OOAM P WELL TEST: initial 4 - Year Workover Other(1) YR. ANNUAL AOGCC REP SIGNATURE ;ftlu� 01. Z10 OPERATOR REP SIGNATURE Zlaan JC9KD3BD.XLS 3-� ARCO Alaska, Inc. 4, P.O. Box 100360, `,,,.�.orage, AK 99510 %L Date: May 24, 1994 Transmittal #: 94040 AA Subject: ARCO Cased Hole Finals From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 ofd <? To/Location: Distribution �-,51 ar�oh Well Log Dane Tool Type Run, Contractor Number (M -D -Y) Scale 'ss'o �p 38 OWDW- 4-29-94 PITS 1,511 SCH o� SW qty_ 1-9A 5-14-94 Perf Rec 1,511 SCH 14to 1-20 5-7-94 V Perf Rec 1,511 SCH gyp.- 2-4 5-11-94 Prod Prof 1,511 SCH 2-4 5-11-94 CNL 1,511 SCH 1j 0- 2-5 5-7-94 Prod Prof 1,511 SCH 2-5 5-7-94 CNL 1,511 SCH gjp- ;w 2-18 5-8-94 Prod Prof 1,511 SCH SZ, 2-20 4-30-94 Prod Prof IV, 1,511 SCH 2-20 5-13-94 CNL 1, 5 SCH 3-19 4-4-94 Bride Plug 1,511 SCH c�- 3-29 5-3-94 1 Bride Plug 1,511 SCH 3-32A 5-9-94 ALISIT (Cem & Corr 1,511 SCH 3-32A 5-12-94 ✓ Perf Rec 1,511 SCH I 4-5A 5-17-944 Perf Rec 1, 5" SCH 4-5A 5-17-94 USIT 1,511 SCH 5-6 4-30-94 Prod Prof 1,511 SCH 5-35 5-3-94 TDT-P 1, 5" SCH 6-10 4-5-94 Leak Detect 1,511 SCH � t p 6-11 5-14-94 �F'acker Set Rec 1,511 SCH qj -- ST 6-22A 5-14-94 Perf Rec 1,5 SCH 11 7-3 5-8-94 Prod Prof 17511 SCH 7-3 5-7-04 Perf Rec 1, 5" SCH 7-23 5-10-94 VJewelry Set Rec 1,5' SCH 7-23 5-15-94 om letion Rec 1,510 SCH q. - 025 9-13 5-16-94 Bridge Plug 1, 5" SCH J3q- -* 9-26 4-6-94 v1 Perf Rec 1,511 SCH '70- 82, 9-42 5-15-94 \/ Leak Detect 1,111 2" 5" SCH 110- 9-47 5-16-94 V Packer Set Rec 1,511 SCH Olt,.(.... o&o 11-36 5-18-94 USIT 1,511 SCH `g -- 12-813 5-4-94 ✓ Prod Prof 1, 1 " 5" SCH SI 13-8 5-2-94 In' Prof 1,511 SCH (1( �lL(- 13-31 5-2-94 ✓ USIT 1,511 SCH .11 13-35 5-10-94 USIT 1,5 SCH :7$- 14-7 5-13-94gual bin Patch Rec 1,5 SCH f3� 14-15 5-17-94CNL 1,5- SCH qZ- q(v 14-41 5-8-94 Burst TDT-P 1,511 SCH V.- 16-26 5-6-94 Perf Rec 1,5' SCH q2.-- 111 17-19 5-12-94 V Perf Rec 1,51' SCH �j 18-1 5-16-94 ✓ Perf Rec 1,5 SCH �33 to"�IP 5-15�i�(�� ARCO Alaska Inc. Is a Subsidiary of AllanticRichflsldConpany MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John DATE: May 1, 1994 Chairma 11, Blair Wondze! FILE NO: jc9kd3bd.doc P. I. Supervisor FROM: Jerry Herring, `� SUBJECT: Mechanical integrity Test Petroleum Inspector ARCO, Pad 3 Disp. Wells Prudhoe Bay Unit Friday, April 29,1994: 1 traveled to ARCO's pad 3 and witnessed MIT's on the (3) oily waste disposal wells. The Mechanical Integrity Test Report is attached. The disposal wells were shut-in for the tests. The wells are shallow, disposing of waste oil and water in the Cretaceous zone at 1,880 ft -1,890 ft. The MIT's were completed without any problems. Summary: I witnessed the successful MIT's at ARCO's pad 3 at Prudhoe Bay for oily waste disposal wells OWDW-SE, OWDW-SW and OWDW-NW. Attachment: jc9kd3bd.xls 7 { S w MEMORANDUM TO: David Johns , Chairma THRU: Blair Wondzell, �' 3 P. I. Supervisor FROM: Jerry Herring,��` Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 13, 1993 FILE NO: jh-rep44.doc SUBJECT: Mechanical Integrity Test ARCO, Pad 3 Disp. Wells Prudhoe Bay Unit Thursday, April 29, 1993: 1 traveled to Prudhoe Bay Unit, EOA pad 3 and witnessed MIT's on the 3 oily waste disposal wells. The Mechanical Integrity Test Report is attached for reference. The disposal wells were shut-in for the tests. The wells are shallow, disposing of waste oil in the Cretaceous zone at 1,880 ft -1,890 ft. The tests were conducted starting at 1,600 psig and lasted for 30 minutes. The MIT's were completed without any problems. Richard Ortiz with ARCO was well organized and had a good crew and equipment on the test. Current wellbore diagrams were provided by Richard for the 3 disposal wells and are attached for reference. .Summa[y: I witnessed the successful MIT's at ARCO's pad 3 at Prudhoe Bay for oily waste disposal wells OWDW-SE, OWDW-SW and OWDW-NW. Attachment TIEze�e are -A e-ra ^ a 4 M t7 [0/7 0Ar GG: �errcc SC%vrel C� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD /UNIT /PAD: DATE: 4-L21A3 WELL NAME *P *S *N TYPE ANNULUS FLUID PACKER TVD MD CASING SIZE / WT / GRADE TBG SIZE REQ TEST PRESS PRETEST TBG CSG PRESS START TIME TBG CSG PRESS 15 MIN TIME TBG CSG PRESS 30 MIN TIME TBG CSG PRESS START TIME P F owl -SE A D DrESFL lags, I�� g, ���'z � � �- 5 /s # -8� 2�,1 ��.� ��a . azo «o �Zo lo:g.��, P /8�5 D oo / COMMENTS: .z P i5 ow Dw - 6 w .p I 913 15 7Z - �/ 8D ¢ p 1 ' 2 $ too �o LT - a o 1S ��O I /5Z o l i 3G,n COMMENTS: N PIE! SQL b 7 Z .� ,/ ,. � 2 %s 50 f ov 301'."5 COMMENTS: COMMENTS: AAl •ft •r& ITA_ Iw%.#4V18w1&_4 % a W. Ir 1 *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING P- DISrosAL Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector ANNULAR FLUID: GRADIENT: WELL TEST: DIESEL Initial GLYCOL 4 - Year SALT WATER Workover DRILLING MUD Other OTHER OTHER AOGCC REP SIGNATURE OPERATOR REP SIGNATURE U uw Fi-051 L3 Rev. 12/93 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 10/23/96 WELL -NAME: PRUDHOE BAY UNIT OWDW-SW API: 029-21817-00 LEASE: ADL -28311 OPERATOR: ARCO ALASKA INC FIELD/POOL: PRUDHOE BAY, PRUDHOE UNDEFINED SALES CD - ACCT GRP - FINAL STATUS: SER WDSPL CURRENT STATUS: ** DISPOSAL PROJECT ** 1986 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH DAYS OIL WTR GAS 1986 TOTALS OIL WATER 31,131 GAS CUM OIL CUM WATER 31,131 CUM GAS 1987 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH DAYS OIL WTR GAS 1987 TOTALS OIL WATER 187,441 GAS CUM OIL CUM WATER 218,572 CUM GAS 1988 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 21 14 13 23 23 28 29 15 27 30 30 OIL WTR 11,601 6,083 5,267 23,903 23,903 66,155 77,462 11,068 33,217 31,137 34,144 GAS 1988 TOTALS OIL WATER 343,690 GAS CUM OIL CUM WATER 562,262 CUM GAS 1989 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 21 25 31 12 4 29 31 30 29 27 24 OIL WTR 12,966 27,930 46,303 28,384 3,380 42,980 62,590 31,851 33,708 24,161 16,278 GAS 1989 TOTALS OIL WATER 362,202 GAS CUM OIL CUM WATER 924,464 CUM GAS 1990 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 29 27 31 29 28 30 30 30 30 31 29 OIL WTR 30,906 15,865 32,705 39,546 56,300 49,745 43,187 39,049 50,414 32,758 30,589 GAS 1990 TOTALS OIL WATER 442,252 GAS CUM OIL CUM WATER 1,366,716 CUM GAS 1991 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER OTHER DAYS 14 9 16 16 28 30 31 31 28 24 17 OIL WTR 8,782 3,721 14,550 12,508 36,479 74,366 43,294 54,363 19,668 8,973 15,865 GAS 1991 TOTALS OIL WATER 293,693 GAS CUM OIL CUM WATER 1,660,409 CUM GAS DEC OTHER 31 31,131 DEC OTHER 31 187,441 DEC OTHER 14 19,750 DEC OTHER 30 31,671 DEC OTHER 31 21,188 DEC OTHER 9 1,124 ARCO Alaska, Inc. P.O.Box 100350 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO CASED HOLE FINALS 00"S -18A Y-112- 430-93 3-28A �� -,2 3 4-26-93 3-25A 4-26-93 3-315 - 2 426-93 «rr 3-32 p -7 4-25-93 " 75-- 0 423-93 oo • 5-9 77-3y 4-2493 oww--p-13 $ 0-30 4-27-93 ,,- 9-5A y'3 4-29-93 ,o► -9-15A 5-1-93 9-28A °tL 4 34-24-93 ;, -36A g3.3� 4-26-93 0000...9-36A--,-, 4-26-93 r,�-14SiT S/-/385-1-93 „�.••34-3 rX,;, '2 8-2-93 va "z )JI V -NW 4-30-93 -BE 4-29-93 ....,,.QWDW-SW 434-93 Completion Run 1, W Sch Perf Record Rim 1, W Sch Jewelry/GR/CCL Tie -In Run 19 W Sch Leak Detect Run 1, V dam' Sch Leah Detect Run 1, VWX Sch Dual Burst TDTP (Borax) Run 11, tfi' Sch Production Log Run 19 W Sch TDTP (Borax) Run 1, is' Sch CET Rim 11 ly, Sch PITS Run 1, h~' Sch Static Pressure Survey Rim 1, W Sch Compensated CBT Color Run 1, 5" Sch USIT Color Run 14 61 Sch Completion Run 1, so Sch Completion Run 1, 61 Sch PITS Run 1, W Sch PITS Run 1, W Sch PITS Run 1, W Sch Please sign and return the attache py as receipt of data. RECEIVED BY__�" Have A Nice Day! APPROVED Trans# 93058 --- Sonya Wallace ATO -1529 )f r `' # CENTRAL FILES �� PHILLIPS # HEVRON 44 /IrWELL D 8c M �dska �4y / � D # CLINT CHAPMAN ��/� has X9'9 BPX # EXXON A'70ho� CQ #STATE OF AKA ON�a � � &CO # MOBIL ALASKA OIL AND GAS CONSERVATION COMMISSION May 18, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Harold M Scott Environmental Engineer US EPA Region 10 WD132 1200 Sixth Ave Seattle WA 98101 Re: MLTs on Arco Class I Wells Prudhoe Bay Field, Alaska Dear Harold: As you requested, we witnessed the MLTs on Arco's Class I wells in the Prudhoe Bay Field. These MITs were conducted by pressure testing the annulus. Tests were conducted on the OWDW wells SE, SW, and NW. All wells passed. Details of the tests are contained in Petroleum Inspector Harold Hawkin's report which is enclosed. If you have questions, please call me at (907) 279-1433. Sincerely, Blair E Wondze P.E. Sr Petr Engineer Enclosure ARCO Alaska, Inc. P.O.Boz 100360 Anchorage, Alaska 99510 DATE: 5-15-92 REFERENCE: ARCO CASED HOLE FINALS 7S' 7 7 4-78T i~yam 5-8-92 PD8100/GR/CCL Morax) Run 1, &1 Atlas 4-10 5-2.92 Inj Prof/Caliper Rum 1, 51 Cameo 4-17 5-2-92 Inj Profile Rum 1, &I Cameo 2_8 4-34A 4-30-92 Jewelry Rum 1, 8' Cameo 88 t 5-2-92 Prod Profile Rua 1, ar' Cameo 5$92 PDH 100/GR/CCL 03oram) Rim 11 W Atlas rZc33S 8 9.38 5-9-92 CCI, (Pert) Rum 1, &1 Atlas 8 0 _ ?1 17-3 429-92 Prod Profile Run 1, !f' Cameo OWDW-NW 5-3-92 PITS Run 1, 61 Cameo 00 „ 23 9 OWDW-8E 5-1-92 PITS Ran 1, St Cameo 0 0 — 70 8 OWDW-8W 5-2-92 PITS Run 11 W Cameo 71'S/ Term Well A 548-92 CCL (Pert) Run 1, W Atlas Please sign and return the attached copy as receipt of data. RECEIVED BY Have A Nice Day! RI E E j C D Sonya Wallace MAY 2 1 1992 APPROVED___ ATO -1529 . Trans# 92101 Alaska Oil & Gapons. Co:n��ss'on A # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF �9►I.A.SHA TEXACO MEMORANDUM State of Alaska ALA KA OIL AND GAS CONSERVATION COMMISSION TO:Lonnie C Smi DATE: May 5, 1992 Commissione FILE NO: hh555-5 . doc AA TELEPHONE NO: THRU: glair WondzelAA SUBJECT: �t Mech Integrity Tests P.I. Supervisor AAI,PBU,OWDW,SE,SW,&NW Prudhoe oil Pool FROM: Harold R Hawkins Petr Inspector;;(Xj01,0, Friday. May 1. 1992 I witnessed the mech integrity 'tests on AAI, PBU, OWDW, SE, SW, and NW wells. They all passed. They were tested correctly in accordance with AOGCC regulations 20 AAC 25.030(g), 25.412, 25.252(d) and AIO #4. I also checked back and forth on the temp surveys of these wells Friday through Sunday. I picked up copies of MITs from July Heusser with ARCO and filled out an AOGCC report. In summary, the mech integrity tests and temperature survey logs were satisfactorily performed. Attachments 02.001 A Mev. 6/89) 20/1 1M EMOl.1'M9 PRUDHOE BAY OPERATIONS ENGINEERING INJECTION WELL ANNULUS MECHANICAL INTEGRITY TEST Pre -Test Starting (30 min) Final Start Time/ Water Type/TVD Minimum Packer Pre -Test 9-5/8' Starting 9-5/8' Final 9-5/8' Pass Pressure Bled To/ Gas Annuius Test Casing Tubing Depth Tubing 13-3/8* Tubing 13-3/8* Tubing 13-3/8* or Time Bleeding Completed Well MI I/NI Fluid Press Size/WT/Grade Size TVD/MD Press Press Press Press Press Press Fail W O,ly QO 174a 173 Comments 330 hr. PRUDHOE BAY OPERATIONS ENGINEERING INJECTION WELL ANNULUS MECHANICAL INTEGRITY TEST Pre -Test Starting (30 min) Final Start Time/ Water Type/TVD Minimum Packer Pre -Test 9-5/8' Starting 9-5/8' Final 9-5/8' Pass Pressure Bled To/ Gas Annuius Test Casing Tubing Depth Tubing 13-3/8* Tubing 13-3/8* Tubing 13-3/8* or Time Bleeding Completed Well MI I/NI Fluid Press Size/WT/Grade Size TVD/MD Press Press Press Press Press Press Fail W O,ly QO 174a 173 Comments Ml �■■ice—���� MEN ��oWIME- 11MWINIMMIMM r+w%,%j rriumbs oignaiure: hate: z IL/ f9Z' Cts tYf't1 Wells Group (PRB #20) PRB Central Files (Remedial Section) ` ARCO Rep. Signature: dM He x r Date: 5/1 42- ATO Opers. Eng. Well File (W5-3 Section) Mi- RLL: 2aaz4uttict by H • k i his— M. L. SM , - tT0 1528 0900 hr 09 as hr Date s 1 Company f ALASKA OIL AND GAS CONSERVATION COMMISSION MECHANICAL INTEGRITY TEST X -Field PRETEST ANNULAR FLUID: GRADIENT: WELL EST: Initial 4 -year Workover Explain 6 ��zl.A Z P = PRODUCE WATER INJ DIESEL 0,0 START 15 MIN 30 MIN GLYCOL t 6 Of'q M = - ,%'Z0A,-' 4'614� 0,r=f AS al-, *TUBING INJECTION FLUID: ANNULAR FLUID: GRADIENT: WELL EST: Initial 4 -year Workover Explain 6 ��zl.A Z P = PRODUCE WATER INJ DIESEL 0,0 370 S = SALT WATER I NJ GLYCOL t 6 Of'q M = efl *P *1 TYPE OF PKR CASING TBG REO TIME START f fro ., ., , ,� ., yd TBG TIME TIME WELL *S - ANNULUS TVD SIZE/WT/CRAOE SIZE TEST CSG TBG TBG TSC TIME- P F NAME *M *N FLUID MO PRESS PRESS CSG CSG CSG PRESS PRESS PRESS owp s � rnuururc_ /7190 - ,%'Z0A,-' 4'614� 0,r=f AS al-, *TUBING INJECTION FLUID: ANNULAR FLUID: GRADIENT: WELL EST: Initial 4 -year Workover Explain 6 ��zl.A Z P = PRODUCE WATER INJ DIESEL 0,0 370 S = SALT WATER I NJ GLYCOL t 6 Of'q M = efl SALT WATER I - COMMENTS: DRILLING MUD N = f fro ., ., , ,� ., yd ,:3 -- a � ` 9a #g"16y re A Al AOGCC WITNESS SIGNATURE 1770 117,a4) 1�17j COM14EN TS : COMPANY REP SIGNATURE C.00G (rev 05/10/901 - ,%'Z0A,-' 4'614� 0,r=f AS al-, *TUBING INJECTION FLUID: ANNULAR FLUID: GRADIENT: WELL EST: Initial 4 -year Workover Explain 6 ��zl.A Z P = PRODUCE WATER INJ DIESEL ' S = SALT WATER I NJ GLYCOL t 6 6 � N r/i «1d ti hof M = MISCIBLE INJECTION SALT WATER I - INJECTING DRILLING MUD N = NOT INJECTING OTHER _ OTHER AOGCC WITNESS SIGNATURE COMPANY REP SIGNATURE C.00G (rev 05/10/901 04 '23/ 92 06-23 FAX 206 553 0165 wA`ihx ])IYIb1UN W-1 UOl / 004 m U.S. EPA Region 7 0 Water Division Tne Phone No: qo7 ins. i1V3] City, State/Region: p 1t w /T FAX NUMBERi607) a?6-V90*-. FROM: sg#A&& zgerr - i 1200 SbM Avenue, - 43AL Seattle, WA 98101 Phone No: Jot "or/ TOTAL PAGES: (including this cover sheet) 0 COMMENTS: of/ ro &Alto "m 11m0* �. �trAAe�o C�+� Z w�• PA64aw A& -'s4 Jr- � RECEIVED /T APR ?31992 ,.awaSKa w & Gas Cons. Commission. k Anchorage UV . Lei i'Ah GUV 000 V1VV fi:aIL.Ak vl i 1`.71 V1. ARCO Ala4ka in Post Office Sox 100360 Anchorage, Alanka 49510-.036o Telephone 907 276 1215 March 28, 1992 Mr. Harold Scott ndergraur�d Injection Control and program Support Section AP1 U.S. Environmental Protection Agency 1200 Sixth Avenue .Seattle, Washington 98191 Re: Permits AK -11003-1, AK -11004-1, and AK -11005-1 Temperature lag information and notice of 1992 MIT and temperature logging. Dear Mr. Scott, As discussed by phone, I am enclosing the past temperature logs and . supplemental information provided to Mr. Tim Wingertor of the Alaska Department of Environmental Conservation. We have provided copies of the logs from the perforations in the injection zone through the lower level of the confining zone. , Pleaw. note that the upward depth of temperature change has not changed over the years. The constancy of theses results supports revision of. the test from an annual basis to a less frequent basis. we agree that EPA's proposed 5 year schedule would be approOrlate. This letter will also provide the advance notice of the 1992 mechanical integrity tests and temperature logs. These tests are planned to commence May 1, 1992, at 8:00 a.m. While we would be interested in postponing the temperature logs to see if a less frequent schedule is possible, we do not feel we can do so unless written authorization from ADEC and EISA provides us clear direction for postponement. If you nP.ad more information or have questions pleaso cll Bob Elder or me at (907) 559-5195. Sincerely, R E C E I V E D Rod offman Director, Field Environmental Compliance ` 1- F=.ia3�iCi uil & Gas C —is. Commission cc. T. Wingerter, ADEC Anchorage AACO Alaska, tnc. jaa Subsidiary of A11Anti0;Riehtie1dCamvaAy AR38.400-3C • .�. . .Y, `eF""'a•�'., +.Z•"�... _ _... ....J - :«ir.... ti•KaR :..:.. _ _o. i,.,.i-,w,_.w+.:w, h :. �.(�. ._ �. n • � - ..r„p.. !N.v�.' awjw.rJ�4"1�.4T .. s ._ fXw'_' + . -. ^_..... - .. _ - 3�"$-c-�Tvr:��- i . .. ARCO ALASKA; ` I NC '. .P.O. BOX- .1.00360 _ -_ _ _ ��. .w a _.. _�. _�. a `,.• �,R� � _. _ _ ANCHORAGE, ALASKA 995 DATE -91 _ • a r -•-- :�,re ?+-- ,._.__. .....r.,.+ -.e.:,... :.c`� �'....,...+..r...:i...i»......>--.»--"T'------ REFERENCE: 'ARCO CASED HOLE FINALS' - 3-3 a,-4 7,. 91 TEMPERATURE RUN. �� 5' .F`;MK HRS - * 6--1 TUBING -CUTTER �U�! i;7�.5.` � :-: A�"LAS.... 12 — 8 B '' '" =�i =9i CALIPER & 0! 0WDW- IW...,�5 2.-9 �_. PITS --,�:.�--. ..,�,... .t.._-: ,.=.� 1J�! .. _-.CAMGII .. OWDW—SE 4'S -t 1-.91 FITS '�� w } „ . y ,3 yRUN ta'i :�} '� f _- CAMCO } .., y -: , ..2�-•OWDW—SW ...:�tS+ ---�.�... r F' -I TS - fl -7 _ GAMCII _ A 1A F'WDWi —i r. 4= 4-qi. !INJECTION_ {:P OF'ILE Xr��� t �. ;� � �Ag REIN 'i:��.' � � ��� :CAMCO _.PWDWi-2A 4 -2q ---9i INJECTION ;PROFILE--_ ... �._._ _.___�:._. ... 11 1 : `:,. '.. CAMCO _ PLEASE .SIGN -AND RETURN-- THE AI'�'ACHED COPY AS RECEIPT OF DATA - .y' �:y;{. ".i'a`_ ..y • � �l t .n� �.. � #- '.�'- � - _�,.�;��3-� _ is ,..� i ��+�.K r�s �-` - _ 4s-. ��J� �.t,�+,,;7 = I A.,, �?"'` ..:st?•"�'t�l"`Y'4 rw " rF .zr '�iy 4 ,x�:.- xt ,� �.a.•.`-.,st� �-a-4z'�-ar. • RECEIVED ���;r. hx` _ { 3..• s �, 5 - t_z3y •.ftv�x�:" � 1�� �"�*Feas � �:,-, �'�,' � �. - - ^ � - ` t _.... �-+i S -,,F #y.'. y.i • '�3,,'w%P �ri�t�t+w�+�-.._. +a.• .a•.x »�s.+..ss:.=.....r.-`f�"'� 9T ..#,. �+;ra-i+=.��. "¢ - `� . - +c« -w a..r�--s.�4AF--•";: . -. .,.ei:«...�'w?�+;��iM�i'A'�;.c..,.__-+-.i.......�. �','•.+P,,�':5• ,y-��.. :.r: c t-* -3lt - r'i;' •'�-..-.. - �• .a :-,.�...t'•: HAVE ..a �. F LiF`F'Fiti1ED4 S O N Y A ._tjA L t . � �' JF� ..yam. _ ::nSi'n`�� '� *�' i•i a�i, �13S -.r _a.. ]L [i: _ —" T -O ^.�'f 2. w + +sn►«.s +itl y. <ae: tw 4 r r q'i4 L ;34�s :}. �--:J'. dt '► ' ^a. A+{� .�.�,,r t: 'ii.-�+.. ;*ate �- _ -� � _ �� �'� ��• . _.. •.. , .. ...„„::�:rt;..iit " ���w•-^ , - �.. ,.., � c.»..,,..,�.'c-rr.�a�'� F`'yYV.✓ ..ee+r=fit-=."'°'�-� -zn ,,'--�-•�-.. ;i`r7 � y ,.,..,,�_ .tt 'tea .t4;`. 1-'.� ,'?•' + -Frf, ,r: _ S t..`: xr. �'�'Mx' .�.r�a'= w -_r ,.=.�' :-.1=u 3, -'r :; 'lt.+: •,rr�; r.`�s-+ _ .0 '('_`"...: -ca°i - „�.._. .z =4 ..a :: �? i 8yp+,,'.-ter - ,, 1 &e 01 T T �rrr+++i _-t•Yae i ya„s ,. .. ZZ_ZZ_....t._r..-:_..�_.....+ D I Y i' R f _r• m .. r •.• 'C�1't'C� A I ..: L� i 1 C t' ` •' '����_f ,`�e€ ' i ...1!ii+a�s.�eJ:S. `' z U�!jj. }�RON. ?.. � • ...-.••_ «, .. .'.t - � fan �� -x 'EXTENSION EXPLORATION -'X -s. J.UN. ,. r--STT£_rOF� ...ALASK A. " .._ _ N' ..i• •' fr`► _. y. rYf csh ". _.-s.'* 1• .a-•�;y!" 77 :MARATHON K TEXACO , x ._. T.HE� f r_ ** THE "CORRECTED AF' I; FOR 2--8B ` I S 50--029— 0432-02 C El VEU� 77 ,..�..w.«...r..+.MOs�+4.�.q.s!rr.••Ya+.+"`w"^�_.....-.....w..-..,_....._....._...•..y�.w-»w -... '...*""rI�` _ :'-. Q Bt 'CxdS-GtiAS.�COmmugs 4A� -�-�- .._... �.. ,..Anchorages �,> { .- J r ..• .. ►-.._..F�—.r.�.r�s7�- ' - +w.+w►-*�«.a,..-,v+•...w...tw.i�.�.�.YwW_.��T+..11bs.G-L+s.�`•rs�•wea.�s•.•srwwrw..-.-..F.r_•. ,.`.N.R�a.+- .... .,•. �.. r r htt "a 6,',y�'" •.. .:_^.- '.:• .-s. Yy ,� � � - k _r �r ,. -.3;, 4 r - _ - r ` _-......__.,.... .... t'.+... t+�.ri�dr.:rM•w+•.r �..._��... �....-.....,.._ i,,, .+•ew..�-f�xi-s.��s!*�.s s.+.+.r.�+++r « ..r.•w-w-+•.*+c.Kwr«-rNa•.j•y�,r+.�+(t�`.'s'� ,"t'r `R �y '.':�a'�k''rY�.. %H�,"�i.7'}. _•y`•�••`,k ;{.' .. rf �L',e Y_�.t �pY t v . j 2 s.-`� '+s� :� f ; L fiv}K`.}-�3r�'� s�d-r ,, - t ...-...+..+w+rsw.sww.y«•rsa.. �.. a' .. .,r 1 �"Y - - Y� x.�,w J -t.,C. l.� ir, t v.y.. - - �;i� .t it:. - x z=t x r�-�`•t%'A �' +r y'- •r:. • - - ! �� t. -T< ..:3,.`.f,� f�4+a�.-Ui�ga, r _ � �` ,£ ���g�a � x µ"� �• .-.i rs> `�� -�1 `s zj "`�, u- •, �x �'- •3- ' _ m; k /ri f � - f�A -a� ,�.«�►y�w,y�ir.._+ "' :+t•.�y�2!a '' �- f -+�,,� _ .;_.E., .�ri. ._._. ...►-.w .• o'(•!•i.as4!'Y X•.MfYyiM��*�'►"^s+aCq ..._.. _...._.. _r-..�. r.ny� .. -. �• r � t� �� .i✓� " ' .,_ .. - .'i .Gi�r. .••, - +.. -. Jr..r..,,_..,� ..,. W.•rnM•6Y.a_+N.=.w .,w•_.... s ..a-. -��i. .ewn1E {...aKia.. ✓'nr.�.r'eilt^ �Y••aa--n.. ... __t. _v+_ .r., u..i. �. r MEMOqANDUM St`te of Alaska ASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi May 9, 1991 TO: Commissioner DATE: THRU: FROM: Doug Am � Petroleum Inspector FILE NO: DA59-4 TELEPHONE NO: SUBJECT: Mech Integrity Tests AAI PBU Pad -3 Prudhoe Oil Pool Wednesday May 1. 1991: I travelled this date from AAI KRU to AAI PBU Pad -3 to witness the annual mechanical integrity test on AAI's oily waste disposal wells N.W., S.E., and S.W. The tests were witnessed by representatives from DEC, EPA and myself. As the attached AOGCC mech. integrity test form indicates, all wells were successfully tested in accordance with all applicable AOGCC regulations and Area Injection Orders. In summary: I witnessed the successful mech integrity test on AAI PBU Pad -3 N.W., S.W., and S.E. oil waste disposal wells. These tests were also witnessed by representatives from DEC and EPA. Attachment. 02-00 1A (Rev. 6/89) 20/1 YMEMOLPM3 Date MA,/ I I I aq I - Company A A I ALASKA OIL AND GAS CONSERVATION COMMISSION MECHANICAL INTEGRITY TEST W Field PA7UbH0e 54 y *TUBING INJECTION FLUID: P = PRODUCE WATER INJ S = SALT WATER INJ M = MISCIBLE INJECTION I = INJECTING N = NOT INJECTING D.EWS.06 rev 03/17/89 ANNULAR FLUID: GRADIENT: DIESEL AOGCC WITNESS SIGNATURE �L45'-uc� GLYCOL , q-87(20 SALT WATER COMPANY REP S I GNATURE JM 44,4,,� DRILLING MUD OTHER OTHER 20 AAC 25.030(a) 20 AAC 25.412(c) 20 AAC 25.252(4) i PRETEST START 13 MIN 30 MIN *P *1 TYPE OF PKR CASING TBG REQ TBG TIME TIME TIME WELL *S - ANNULUS TVD SIZE/WT/GRADE SIZE TEST CSG TBG TBG TBG START TIME & COMMENTS NAME *M *N FLUID MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS N W OW bW O N jC-rLjWL 1884 ��%Z �'% - 23 ��o� eta (o t0 pro 8: r�-O A.M. P�15S p O ! g I 1 g2O *TUBING INJECTION FLUID: P = PRODUCE WATER INJ S = SALT WATER INJ M = MISCIBLE INJECTION I = INJECTING N = NOT INJECTING D.EWS.06 rev 03/17/89 ANNULAR FLUID: GRADIENT: DIESEL AOGCC WITNESS SIGNATURE �L45'-uc� GLYCOL , q-87(20 SALT WATER COMPANY REP S I GNATURE JM 44,4,,� DRILLING MUD OTHER OTHER 20 AAC 25.030(a) 20 AAC 25.412(c) 20 AAC 25.252(4) i ARCO ALA%KA, INC. P^O. BOX i0O36O ANCHORAGE, ALA%KA DATE: 6/1/90 REFERENCE: ARCO CASED HOLE FINALS 1-17 5-16-90 4-13 5-15-90 6-6 5-28-90 7-20 5-20-9O 7-27 5-19-90 7-28 5-21-90 12-27 5-20-90 13-33 5-20-90 14-8 5-17-90 14-9 5-18-90 OWDW-NW 5-18~90 OWDW-SE 5-19-90 OWDW-SW 5-19-90 PRODUCTION PROFILE RUN i, 5" CAMCO INJECTION PROFILE RUN i, 5" CAMCO PRODUCTION PROFILE RUN i, 5" 'CAMCO PRODUCTION PROFILE RUN i, 5" CAMCO INJECTION PROFILE RUN i, 5" CAMCO PRODUCTION PROFILE RUN i, 5" CAMCU INJECTION PROFILE RUN i, 5" CAMCO PRODUCTION PROFILE RUN i, 5" CAMCO PRODUCTION PROFILE RUN i, 5" CAMCO PRODUCTION PROFILE RUN i, 5" CAMCU PUMP -IN TEMP SURVEY RUN i, 5" CAMCO PUMP -IN TEMP SURVEY RUN i, 5" CAMCO PUMP -IN TEMP SURVEY RUN i 5" CAMCO ' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA, RECEIVED B EIEf- I�rtru- HAVE�� ^ A NICE DAY/ ' JUNJ- ,&° ���� xw�w SALLY HOFFECKERAPPROVED `L`' ATO -1529 �����\���Gas GOn�WDmluswo,^ TRANS' 90H0-- D%%TRIBUTION � CENTRAL FILES # CHEVRON Nw-'� W, , I � EXTENSION EXPLORATION � EXXON MARATHON � MOBIL _ - ' ' � PHILLIPS PB WELL FILES R&D � BPX � STATE OF ALASKA TEXACO TO THRU FROM: MEMORANbUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. SmiDATE: May 23, 1990 Commissioner t J FILE NO: JT . HH . 5 23 TELEPHONE NO: SUBJECT: Mech Integrity Tests AAI PBU Pad 3 SW,NW,SE EPA Class I Industrial Waste Disposal Wells Prudhoe Bay Field Harold R. Hawkins �j Petroleum Inspector."a'/ Friday May 18, 1990: I witnessed the Mech Integrity Tests on 3 wells; AAI PBU PAD 3 Class I Industrial Waste Disposal Wells SW, NW, and SE. Dennis R. Timmons, ADEC Rep, was also present to witness tests. I helped Dennis with the figures and explained what we are looking for in the tests. He thanked me when the tests were over. I gave him a copy of my field report and different ways to figure MIT tests. I filled out an AOGCC field report which is attached and also received a copy of tests from AAI. In summary, the Mech Integrity Tests on Pad 3 were satisfactorily performed my AAI and supervised by Julie Heusser. Attachment cc: Harold M. Scott; Environmental Engineer 02-OOIA (Rev. 6/89) 20/11/3MEMO1.PM3 Date ,9D ALASKA OIL AND GAS CONSERVATION COMMISSION MECHANICAL INTEGRITY TEST Company AA f Field / /f u war— WELL NAME *P *S *M *1 - *N TYPE OF ANNULUS FLUID PKR TVD MD CASING SIZE/WT/GRADE TBG SIZE REQ TEST PRESS PRETEST START TIME TBG CSG PRESS 15 MIN 30 MIN START TIME P F TBG CSG PRESS TIME TBG CSG PRESS TIME TBC CSG PRESS v 4✓ p w w _> ole W I✓10 4kel, �� .f,f �7�. 0 ; 3 I�6 a o a o G (fG 0 �6 tc;1 , P S —0- 1765 /� 9a /z7PJ .4MENTS : 'NT 'VA r 90 �� 6 /bps /Go COMMENTS: a'017 t�d'��4. 5c WA i �6 !If �5c� _�� .�•��i�'��r_S'� � 3 � 6d �' � ° ~ '� ! �"" �.fG.9M �° S -0 - 170a /a�7�� Alf�� COMMENTS: COMMENTS: *TUBING INJECTION FLUID: P = PRODUCE WATER INJ S - SALT WATER INJ M = MISCIBLE INJECTION I = INJECTING N = NOT INJECTING C.006 (rev 05/10/901 ANNULAR FLUID: GRADIENT: DIESEL be GLYCOL � SALT WATER DRILLING MUD OTHER OTHER WELL TEST: Initial 4 -year Workover Explain AOGCC WITNESS SIGNATURE , COMPANY REP SIGNATURE l ( a-L.� cs Waste N1 Glyco{ /O 1500 r c 2-38 PRUDHOE SAY OPERATIONS ENGINEERING 6400 .ti . aoo INJECTION WELL ANNULUS MECHANICAL INTEGRITY TEST P Water Pre -Test Type/TVD Minimum Packer Pre -Test 5 !L Starting Starting 5 '/2 As (30 min) Final Final u 5 1/1. Pass Start Timet Pressure Bled To/ Gas Well MI I/NI Annulus Test Casing Tubing Depth Tubing Tubing Fluid Press Size/WT/Grade Size TVD/MD Press Press Press Press Tubing or Time Bleeding Completed WDW y 01io r VD6V 1 q KI O s t -7,1 Press Press Fail Comments _I $_ U 18� _ d SW Waste N1 Glyco{ /O 1500 5/i /il*t/N-30 2-38 I8gg 6400 S aoo ��,7o P O VD6V pily Waste KI G(gtcf /p t5oo 5Yz411ir/!-8?� 2-3/� _I $_ U 18� _ (.00 O �— � 1740 -- 0 !0.00 14.40 �E aide /Q Z -3/815S 0 oO 1700 v ONL ta55 a�55 so AOGCC Witness Signature:Date: ARCO Rep. Signature: _41� we"_ le < Date: Z A Distribute: J- M. Heusseer / D. D. Smit ,% (►'ks 2A) Wells Group (ORB #20) PRB Central Files (Remedial Section) ATO Opers. Eng. Well File (W5-3 Sec►ion) ARCO ALASKA) P.O. BOX iO0360 -- ANCHORAGE, ALA%kA 995iO DATE: 6-9-89 REFERENCE: ARCO CASED HOLE FINALS -- 3-9 5-22-89 PRODUCTION PROFILE RUN 1, 5" CAMLO ^3~24 �-22-89 ' GR SPEC.TOOL RUN i, 5" %CH -~3-29 5-26-89 CR SPEC TOOL RUN i, 5" %CH ~-4-i5 55-1'7, 19-89 TEMP RUN i, 5" CAMCO -~ 4-26 5-19-89 PRODUCTION PROFILE RUN i, 5" CAMCO 4-3O 5-18~89 PRODUCTION PROFILE RUN i, 5" CAMCO -~� 5-13 5-20,2i-89 7EMP RUN i, 5" CAMCO �5-17 5-20-89 PRODUCTION PROFILE RUM i' 5" Cf �MCO ~~~7-7A 5-28-89 PERF RECORD RUN 1, 5" %CH -~~ 9-i4 5-22~89 INJECTION PROFILE RUN i, 5" CAMCO -�~12~11 5-2i-89 PI TS RUN i, 5" CAMCO ^~=i2~19 5-21~89 INJECTION PROFILE RUN i, 5" CAMCO ~�~i4-i3 5-27-89 COLLAR/PERF RUN i, 5" ATLAS --�18~21 5~22-89 CBT RUN i, 5" SCH -�~OWDW-NW 5-24'25-89 PITS RUN i, 5" CAMCO —OWDW~SE 5-25-89 PITS RUN i, 5° CAMCO -= OWDW~SW 5~24~89 PITS RUN i, 5" CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY/ E E SALLY HOFFEC � -- i �w-~�~� APPROVED � ��� �-- ATO-1529 �~���,���Y��3 �" TRAN%� 89��1 Oi&GsCns Anchorage DISTRIBUTION A. CENTRAL FILES A CHEVRON,'' D & M' � EXTENSIOt+^EXPLORATION � EXXON MARATHOt+' `� c � MOBIL � PHILLIPS PB WELL FILES R&D � BPX � STATE OF ALASKA A TEXACO PRUDHOE BAY OPERATIONS ENGINEERING I PAD 3,,01LY WASTE DISPOSAL WELL (OWDW) INFORMATION I WELL NAME: OWDW SWC SURFACE LOCATION: 668' FNL & 1064' FEL SEC 11, T10N, R14E BOTTOM HOLE LOCATION: Straight Hole SPUD DATE: 6-24-73 RIG RELEASE DATE: 6-26-73 COMPLETION DATE: 1 -1 - 8 5 TD: 2250' MD PBTD: 2134' MD LOGS RUN: SP/DIL 4 -ARM CALIPER PERFORATION: 1980'-2005' DATE WELL BEGAN DISOPOSAL SERVICE: 1-03-85 CURRENT STATUS: 011y waste disposal well. Mac.OWDW Info Form (3/5/88) a Z, 0 Cid C An Ghoraor, PAD 3 OILY WASTE DISPOSAL WELL LOG OF EVENTS OWDW SW DATE, 9VEN . 06-24-73 Spud well 06-26-73 Log S P/D I L, 4 -arm caliper to 2225' MID Ran 5 1/2" 17# N-80 casing to 2217' MID 06-26-73 Released rig 12-29-84 Converted to disposal well Completion: Ran dual tubing strings 2 3/8" and 1 1/4" 01-02-85 Initial perfs 1980'-2005' @ 4 spf 01-03-85 Injectivity Test 03-24-85 PITS 05-24-85 Interference Test SBHPS: 899.7 psia @ 2000'MD 09-05-87 Mechanical Integrity Test 09-11-87 Run gauge ring, sample bailer Tbg Tail Qa 1928' ELM, PBTD=1988'MD 09-21-87 Tiltmeter test Pad -.3 Oily Waste Dis Wells Name and Number/Designation Lease Number Surface Location Bottom Hole Location Spud Date Rig Release Date Date Completed Well Depths Plug Back Depth Initial Class/Service Initial Status Current Class Current Status Perforations )osal Well (OWDW) Information OWDW SW ADL 28311 (p(pg I FNS, lotPS/ "��z of Sec 11, T10N9 R14E, UM Straight hole 0200 Hrs 06-24-73 2000 Hrs 06-26-73 01-04-85 2250' MD 2250' TO 2134` Thaw subsidence test well Service Class II (permitting in progress with EPA for conversion to Class I) In service 1980' - 2005' Date Well was placed into disposal service 01-04-85 Volume of fluid injected through 07-31-86 789124 BBLS MAM:073.6 10-29-86 PRUDHOE BAY OPERATIONS ENGINEERING PAD 3 OILY WASTE DISPOSAL WELL (OWDW) INFORMATION WELL NAME: OWDW SW. Pru oo- 0238 SURFACE LOCATION: 668' FNL & 1064' FEL SEC 11, T10N, R14E BOTTOM HOLE LOCATION: Straight Hole SPUD DATE: 6-24-73 RIG RELEASE DATE: 6-26-73 COMPLETION DATE: 1 -1 - 8 5 T D : 2250' MD PBTD: 2134' MD LOGS RUN: SP/DIL 4 -ARM CALIPER PERFORATION: 1980'-2005' (1-2-85) DATE WELL BEGAN DISOPOSAL SERVICE: 1-03-85 CURRENT STATUS: 011y waste disposal well. Mac.OWDW Info Form (3/5/88) Ii +d.l�M-• "�— ti ARCO Alaska, Inc. - Prudhoe F -v r Well : OWDW- SW 1 AVT =:50-029-21817-00 Hype: Oily Waste Di Spud Date: 6/24/73 Comcletion:l/1/85 Status:Workover Original RKB- . Hance= Type: FMC Dual H.1—anger: fop of Format=on : 0' ''ax -ole Angle: ° @ 1`=: 0' Angle @ TS Annular Fluid: Glycol Angle @ TD: Reference Lcc: Date:00/00/00 Tie =__. mate: 00/00/00 NOTE: All depths are referenced from ground level =0' to top of equipment. ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry (J) Depth Description 1 1898' _=_ter DB Packer 2 1916' ,.-3/8" Baker R Nipple =_=_.822" . 3 1917' -7-3/8" W/L Re-entry Gu-'z 3 4 1918' Z-3/8" Tubing Tail 1918' _-.M Tubing Tail (Logged 03/24/85) C-1 Min ID: 2-3/8" Baker R Nipple ID=1.822" Casing and Tubing (C) Size Weight Grade Top Bottom Description 1 13-3/?" -2# N-80 0' 100' CaZzlng 2 5-1/2" :7# 114-80 0' 2215' CaS-..� 2-3/8" =.7# N-80 0' 1918' Tud_^c 1-1/4" :.4# J-55 0' 1865' ---:1a Perforation Data (ELM DEPTHS) (P) J-1 Interval Zone FT SPF Date Comments 1 1980- 25 4 01/02/85 _- "FERF J-2 Datum Revision Date: 05/22/93 by PTB J-3,4 8700' SS= :' 1.1c PBTD= 2134' Reason: 4D Z.)W=RSION 8800' SS= :' %D TD= 2215' Previczs Re_sor.: 05/03/91 us RECEIVED APR 0 5 1996 Well OWDW-SW ".'rSka Oil b Gas Cons. Commission Anchorage C-2 PAD 3 OILY WASTE DISPOSAL WELL LOG OF EVENTS OWDW SW DD EVENT 06-24-73 Spud well 06-26-73 Log S P/D I L, 4 -arm caliper to 2225' MID Ran 5 1/2" 17# N-80 casing to 2217' MID 06-26-73 Released rig 12-29-84 Converted to disposal well Completion: Ran dual tubing strings 2 3/8" and 1 1/4" 01-02-85 Initial perfs 1980'-2005' @ 4 spf 01-03-85 Injectivity Test 03-24-85 PITS 05-24-85 Interference Test SBHPS: 899.7 psia @ 2000'MD 09-05-87 Mechanical Integrity Test 09-11-87 Run gauge ring, sample bailer Tbg Tail @ 1928' ELM, PBTD=1988'MD 09-21-87 Tiltmeter test ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 DATE: 9_i6_88 REFERENCE: ARCO CASED HOLE FINAL 2-7 9-12-88 COLLAR/PERF RUN it 5' ATLAS 4% 3-9 8-27-88 PRODUCTION PROFILE RUN i.. 5' CAMCO 4-2 9-12-88 CET RUN io 5' SCH 4-4 8—i8-88 PRODUCTION PROFILE RUN ip 5-1 CAMCO '4%6-9 9-11-88 COLLAR/PERF RUN i.. 5' ATLAS eft 6-12 9-8-88 PRODUCTION PROFILE RUN 11 5' SCH `4457-4 9—i 0-88 COLLAR RUN 1, 52 ATLAS "'"%w7-4 9-10-88 COLLAR/PERF RUN 1, 5' ATLAS 14-13 8-20-88 TEMP SURVEY RUN io 5' CAMCO 15—IOA 9-5-88 CBT RUN i, 5' SCH %-116-4 8-18-88 PITS --GAMMA RAY RUN 1) 2*&5* CAMCO ,***ie—g B-19-88 PITS --GAMMA RAY RUN 1, 5' CAMCO WWDW—SW 8-24-88 PITS RUN i, 5' CAMCO 0WDW—SE 8-25-88 PITS RUN ip 56 CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY ------ --- V E. HAVE A NICE DA SALLY H O F F E C Alaska -OU Z Gas Cons. Commission ATO -1529 t Anchorage TRANS Ar88571 APPROVED_ ------- -------------- DISTRIBUTION A A V CENTRAL FILES v PHILLIPS JL v CHEVRON PS WELL FILES D & M R & D EXTENSION EXPLORATION A SAPC A EXXON * A w STATE OF ALASKA TEXACO AL MARATHON V MOBIL Pad .. -3 Oily Waste Disposal Well (OWDW) Information Wells Name and Number/Designation Lease Number Surface Location Bottom Hole Location Spud Date Rig Release Date Date Completed Well Depths Plug Back Depth Initial Class/Service Initial Status Current Class Current Status Perforations Date Well was placed into disposal service : Volume of fluid injected through 07-31-86 MAM:073.6 10-29-86 OWDW SW ADL 28311 33081S & 1576'E from NW corner of Sec 11, T10N, R14E, UM Straight hole 0200 Hrs 06-24-73 2000 Hrs 06-26-73 01-04-85 2250' MD 2250' TO 2134' Thaw subsidence test well Service Class II (permitting in progress with EPA for corversicn to Class I) In service 1980' - 2005' 01-04-85 789124 BBLS WELL # SW WELL PROFILE 13-3/8" CSG. @ t 100 ' 1-1/4 2.4tt, J—SS, CS HYDRIL TO 1920' 2-3/8', 4.1n, J—SS, CS HYDRIL S-1/2 X 2-3/8' MOREL 'DB' PACKER W/ 10' SEALBORE EXTENSION, XN NIPPLE AND WIRE LINE RE--ENTRY GJIGE @ 1960' 1980'-2OOS' @ 4 SPF PBTO @ 2134' S-1/21'. 1740 N-80, BTC @ 2215' NOV 0 51986 ias,ka oil & Gas Cons. Commission 1 t.nr�r�G 7tt7lQCI 43 FIGURE 1-1 APPROXIMATE 18 MONTH THAW ZONE AT 1000' O'TEMPERATURE HOLES E-5 d E-6 LEGEND SIX 15' MONITOR RODS SIX 30' MONITOR RODS > THREE 100' MONITOR WIRES FOUR 150' MONITOR WIRES �,. TWO 250' MONITOR WIRES THREE 400' TEMERATURE HOLES PERMAFROST THAW TEST SUBSIDENCE MONITOR & TEMPERATURE HOLE 'PATTERN SCALE 1 "= 10' 'C 0 Lacck4lb V% 7 - AI( 11 111.02.1 1111 IeC-1i UnCAIWN W NK7 -7 tsp.0s ft. we -Its - lee • XO.O S2- Oen LePo(?"--- I io SHEET D F. 5. WW ANDf-01-10-14- , : - -m v tR.T, Al,,,ka, vzar CHK. 1A t3,--.SInco r% 3 j A;..i S. Sijb2idiayy r,.t Ailan i4ir.11fititi r.orn;)-,ny DATI 21 -ni SLOPE -,3R11.L"+3-PRUD14CE COY a No APPENDIX I - 1'1ZUD11 13AY FIVE SPOT' TAW SUBSIDENCE T 1. Test Program The 5 -spot thaw subsidence test holes were drilled and the heating; and monitoring equipment was installed during June and July of 1973. A 22 month thaw period will be completed in June 1975. The test utilized five 2200' cased holes in a closely spaced 5 -spot pattern to produce a thaw of approximately 35' radius which represents approximately 15 years.of production from a Prudhoe Bay Field mid -structure oil well. The test was designed to obtain the maximum data and provide sufficient time for well completions prior to field startup. The test was located near the center of the field on BP's Central Pad 3 in Section 11, TION, R14E. Since this was also' -the site of BP's extensive permafrost coring program, the core data could also be used in the subsidence test evaluation. Figure I-1 is a map of the test site showing the arrangement of the five thaw wells and the placement of the temperature and subsidence monitoring holes. Figures I-2 through I-5 are sketches of thaw wells, the subsidence monitoring rod wells, the subsidence monitoring wire wells, and, the temperature monitoring wells. 2. Test Results The 5 -spot thaw pattern was analyzed with an X -Y two dimensional thaw simulation model. The progress of thaw at the 1000' level is shown in Figures 1-6 through I-10 at five different stages of thaw. The equivalent single well thaw radius for the 5 -spot.: pattern versus depth is shown in figure I-11. Until the later stages of the test where the five patterns have merged into one, the equivalent single well thaw radius should be used with caution. I-1 im i ARCO Alaska, Inc. Post Office,',,.,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1986 Blair Wondzell Alaska Oil and Gas Conservation Commission (AOGCC) 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Prudhoe Bay Unit Oily Waste Disposal Wells (Pad 3) Dear Mr. Wondzel1: CL\ C01�lM` Co.,�r J RE i EPS+G � -L SR ElIG SR ENC�---�-.� _ SR_GEO�� SR GEOL- f _ EPJG ASST _Et4Q,SST r' STAT TECI ' !T TECFiI E: As we discussed in our October 16, 1986 telephone conversation on this subject, attached is the data you requested on the Pad 3 wells to update and complete your files since you now regulate Alaska underground injection control matters for these wells. In future correspondence related to these wells, they will be referred to as the Oily Waste Disposal Wells., as a group. The individual wells will also carry the designations NE (northeast), NW (northwest), SE (southeast), SW (southwest), and C (center), which represent their locations on the pad, with respect to each other. If you have any questions or desire further information, do not hEsitate to call me at (907)265-6136. Sincerely, /,�" oe--- Mark A. Major Operations Coordinator Prudhoe Bay Operations MAM/plw:073 Attachments R,ECE11'ED NOV 0 S lggg Alaska Oil & Gas Cons. Commission Anchorage ARCO AlasL. Inc. h r Suhsidiar• c' Atlantick:chlif—:Company W ,F i r�rpr.one 5�- • ��.• August.: 3 , 19 77'' fir. Jim Dorn Alaska Department of Environmental Conservation Pouch 0 Juneau, Alaska 99811 Dear lir. Dorn; Pursuant to our conversation of the supplemental information you applications to inject fluids in located at Prudhoe Bay, Alaska. transmitted to the Department of of Oil and Gas (DOG) . July 22, 1977, I am enclosing requested in support of our three disposal wells This material has been Natural Resources, Division The waste materials which are injected at the Pad #3 Facility (Oily Waste Injection Pad) consist of: wa-ste oils from well cleanup (a mixture of diesel, crude oil, calcium chloride solutions, contaminated with materials such as drilling mud); contaminated glycol solutions, which cannot be regen- erated; waste oil-based drilling muds; -oil -water mixtures from oil spill cleanup efforts; and other miscellaneous oily materials. We currently inject into the "Northwest Thaw Well". As our injection facility is currently being upgraded, additional injection capabilty will be available with the "Northeast Thaw Well". An application covering the later well will be submitted once our plans are finalized. These straight wells are about 32 feet apart and consist of a single string of 5h" casing cemented throughout the perma- frost zone with a special low temperature cement. Cementing the casing in this manner prevents vertical migration of injected fluids once they exit the perforated interval. Attachment l is the daily drilling history of the "Northwest Thaw Well". This shows the drilling and cementing operations. Attachments 2 and 3 are correspondence with Mr.. Tom Marshall, Division of Oil and Gas, which may be helpful. This corres- pondence discusses the well structure, the water formation, and the DOG approval to inject. Attachment 4 is a dual induction log showing the bottom of the permafrost zone and the upper levels of the saltwater formation. No*water samples were taken directly from this we.-L.L. Because this i% !9a6 Page 221 --'' saltwater rock formation is large, thick and continuous throughout the entire Prudhoe Bay field, water samples from � other wells in *his formation are representative of graters in this well. Water samples from oth,er wells were trans- ' mitred with our original application. Attachments 5 and 6 are packages of material describing the ' two water. injection wells, P;IOW 1-1 and PWDW 2-1. These attachments show that these wells are nearly identical in construction and consist of a 20" conductor casing, a 13- ' 3/8" intermediate casing thru the permafrost zone, and 9- 5/8" casing to the injection horizon. All casing strings are cemented in place to preclude any vertical migration of injected waste water. Attachments 7 and 8 are well logs from PWDW Well 1-1 and Well 2-1. From these logs, water salinity can be estimated. As of July 31, -no water had been disposed into PWDW 1-1 or 2-1. To date, water produced with the oil from - the field has been minimal and has not yet required the commissioning of these wells. However, these -two wells are currently operational and will be placed in service shortly. Produced formation water is measured at each oil producing well and is not directly metered at the two water disposal wells. Waste oily fluids are accumulated in tanks at the Pad 43 facility and lnjected into the oily waste well on an intermittent basis. Waste materials are logged as they are brought to the facility; but because of the nature of the materials, they are not directly metered ast:they are injected into the well. I hope this information will satisify your needs, please call. me if you have any questions. ery truly yours , Metz Senior Environmental Engineer Attachments WPM: ew cc: Stan Hungerford - ADEC, Junea- - -.7/o attachments R. G. Hansen - ADEC, Juneau - w/o attachments Tom Marshal - DOG, Anchorage - w/o attachments ' Novem,�e: 10, 1975 ' Mr. Tom �. rshall State of klaslka ' Division of Oil Gas 3001 Porcupine Drive . Anchorage, Alas!" 99501 Dear Mr. • - letter will coafir our telephone conversation. of - • r%6verber 7, 1975, in. ti-aich you gave Atl.zntin P�,Gzi;eld . 'Campany verbal authority to inject oily waste into a ' thaw subsidence test wz311. in Section 11, Towaship IO -•' 24orta, Ra-",e 14 East. Your verbal authority was granted• - ' with the proviso that there were no fresh water sands in. ' the. g_oss interval of the injection. Atlas tic Richfleld Cocpaay dr! 11 ed f ive wells on BP ' • Cenrrai Tad 3 in 1973 for a thaw subside=-e- test_ he - ' location was selected on a BP lease for various reasons which are identified in our Thaw Subsidence Report pre- • sented to you on June 17, 1975. BP has been 'iafor=ed _ of our inteatlon to inject oily waste at the thaw ' subsidence test site and has no objection- The casing '. . pros for these wells included 13-3/8" 72V N-80 Buttress ' at about 1001 cemented to surface and 5-1/2" 17u N 80 Buttress set at about 2250' and ce=entee to surface.- - - i'hep exposed section below the base of Che permafrost-- *fro= about 1850' to. total. depth consists of s t -, sandy • shale. It is our intention to perforate about 3G T as • low as possible and pump in at frac pressure . to dispose ' of the oily waste material. • •• Regarding your proviso, all available data indicates - . fresh water does .not exist in formations below base of 'pera2zost in the area. Two nethods were used to .. ' deteimize the salinity of water in the formation belo•.z _ the-base of permafrost. • These include electric Ida- ogcalculations calculationsfrom the thaw subsidence test cells and a review of core data taken fro= tha interval at the base of per--af.rost is BP Alaska's veli 12-10-14 adjacent to the thaw subsidence test area. The loo calculations • from the thaw subsidence wells at 2100T ind:� ca t e a • salinity of 15,00v ppm NaCl while cores at base of " Permafrost in the 3P Well 12-10-14 had ::ester salinity* of 15,000-20,000 pp.m NaCl. `E L. .FAV 0 5 1986 We. will be happy to sit Co -.•n tli:.i', you to reviec.: this in r_o., 'e.cil s ouI %d you desire. ? =se Z shoulc: - be out the oA`zice, you r.a*lCom ,.act Jerry Rochon for discussion zbout fresh :late_ 2^a Z.z-^y ?yell for Other operzti on 21 iatte:s. Very tru •• yours, - L. K. Villiz s Operations I•Iz«zoer Zia:/��.� • C �•� n r: v: :.��tttti:SSi�� .. ARCO Alaska, Inc. Post Office 1,,100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mr. Blair Wondzell Alaska Oil and Gas Commission 3001 Porcupine Dr. Anchorage,Alaska 99501 October 18,1986 Re:Information requested about PBU oily waste injection wells Dear Mr. Wondzell, To complete and document our conversations of October 14 and 15th, I am providing the following information; 1. The Oily Waste Injection wells are the property of the Prudhoe Bay Unit. 2. Spud and completion dates for these wells are= -as follows; Well Spud date NW June 5,1973 SW IJune 24,1973 SE June 27,1973 Completion Date Rig Tubing released installed June 12,1973 Jan 9,1985 June 26,1973 Jan'4,1985 July 2,1973 Apr 22,1985 3. Total volume injected from 1983 to 1984 was 382,766 bbl. Records were not kept for separate wells until 1985. Total injected volumes since January 1 1985 through September 30 1986 were; 92,027 bbl down the �W. well; 523 bbl down the S.E. well; and 21,939 bbl down the N.W.well. 4. A schematic of the SW well is attached. Please contact me at 265-1345 if you have any additional questions. Sincerely, A V RECEIVED Rod Hoffman Sr. Environmental Coordinator OCT 2 2 1986 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of Atlantic RichfieidCompany t ARCO Alaska, Post Office ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 1 OF October 31, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: #4 SW & #5 SE Disposal Wells Dear Mr. Chatterton: Enclosed for your files/records, are informational copies of sundries describing the workovers that will be done on the subject wells. If you have any questions, please call Jo Ann Gruber at 263-4944. Sincerely, Fithian Area Drilling Engineer TLF/JG/tw . GRU2/L50 Enclosures xc: J. Gruber, ATO 1478 P. N. Hellstrom, ATO 2030 M. A. Major, ATO 1318 Brad Fristoe, ADEC (Fairbanks) ARCO Alaska, Inc. Is a Subsidiary of Atlantic Rich(ieldCompany RECEIVED NOV a 71984 Alaska Oil & Gas Cons. Commisslc,ri pp U.S. EN,-, AONMENTAL PROTECTION, AGENCY s PROISO ATTN Of M/S 437 AN 14 1985 REGION X 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 E.M. Pringle, Vice President Production and Drilling Operations ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Prudhoe Oil Field Class I Hazardous Waste Permit Applications for the NW,"TSE` and SW Wells Dear Mr. Pringle: COMM -�_ 2 EN i_ tr At 2 (, .3 -� CC STAT TE( tONFt-iz: FILE: Your permit applications for the operation of three Class1 wells in the Prudhoe Oil Field as transmitted in your December 21, 1984, letters are complete, conditioned upon receipt of signed Plugging and Abandonment Plans (EPA Form 7520-14) by February 1, 1985. Since the applications did not request confidentiality they will be available for public review. We plan to process the permits in accordance with the following project decision schedule: April 1, 1985 Draft Permits. Fact Sheets Public Notices May 1, 1985 Public Hearing May 10, 1985 End of Public Comment period May 31, 1985 Final Permits issued This schedule may require an additional 60-90 days if public comments justify issuance of another draft permit. Sincerely, Robert S. Burd Director, Water Division cc: C.V. Chatterton RECEIVED JAN 181985 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK'A-OIL AND GAS CONSERVATION t-QMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ❑ OMPLETED WELLX�I OTHER ❑ FOR INFORMATION ONLY 2. Name of Operator 7. Permit No. Alaska State ARCO Alaska, Inc. Disposal 3. Address 8. API Number P. 0. Box 100360, Anchorage., AK 99510 50- 4. Location of Well 9. Unit or Lease Name Prudhoe Bay - Pad 3 10. Well Number NE corner Sec.11, T10N, R14E, UM 11. Field and Pool N/A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: ( in Triplicate) (Submit in Duplicate) rit Perforate Alter Casing ❑ Perforations ❑ Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well ❑ Change Plans ❑ . Repairs Made ❑ Other ❑ Pull Tubing ❑ Other Pulling Tubing ❑ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to perform the following workover on this disposal well: 1. Rig up crane to handle tubing. 2. Run in new 2-3/8" tubing. 3. Run in new 1-1/4" tubing (for freeze protection). 4. Install new wellhead and test to 3000 psi. 5. Rig up wireline unit and BOPs. I 6. Perforate the interval 2104' to 21291. 7. Rig RECEWED down, move off, and shut-in well pending disposal permits. Estimated Start: November 7, 1984 NOV O 7 18988 Alaska Oil & Cas Cons. COmmiSsI Ancho,age 14. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. d Signed - `' itle Area Drilling Engineer Date ��- Th ace be for Commission e onditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date A4 Form 10-403 """" "" Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate • TO; f Hoyle H. Hamilton Chairman Thru: Lonnie C. Smith Commissioner FROM: Ben LeNorman Petroleum Inspector 1ANZA Eli- I MY &/1 paj //t r, Ad I &/V SIL AND GAS CONSERVATION COMMISSION DATE: May 28, 1981 � FILE NO: TELEPHONE NO: SUBJECT: Inspect Arco's Oily Waste Injection Pad #3 Prudhoe Bay Unit. Friday, May 15, 1981: I departed my home at 2:00 PM for a 2:30 PM showup and and 3:30 PM departure via the Sohio charter for ' Deadhorse arriving at 5:00 PM. Weather: +18°F, light wind, high overcast. Saturday, May 16, 1981: B .O. P.E . test on Sohio's N-12 com- pleted, the subject. of. a separate report. Sunday,, May 17,__1981: Witness inspection of Sohio's strainers at Pump Station #1, the subject of a separate report. B.O.P.E. test on Sohio's G-9 completed, the subject of a separate report. Monday., May 18, 1981: Retested low pilots and SSSV's on Arco ` drill sites #2, 3, and 9, the subject of a separate report. Accompanied by Marvin Maye, second line supervisor at Flow Station #3, I toured Arco's oily waste injection Pad #3 adjacent to drill site #6 (photo #1) . The injection facilities (photo #2) are operated by Veco under contract to Arco. r Mr. Maye explained that incoming waste, is first run over a shale shaker to remove solids and then routed to two heated holding tanks (photo #3) . Gardener -Denver triplex injection pumps (photo #4) are utilized to pump into the two injection wells (photo #6) located in well houses (photo #5) just behind the injection facility. A schematic of the two injection wells is attached. Mr. Maye explained further that all North Slope companies utilize these facilities. The two type wastes not allowed for injection are sewage and unneutralized acids. Tuesday, May 19,1981: B .O. P.E . test on Sohio's H-14 completed, the subject of a separate report. Wednesday, May 20, 1981: I departed Deadhorse via Wien flight #76 at 1:30 PM arriving in Anchorage at 3:10 PM and at my home at 3:40 PM. In summary, I inspected Arco's oily waste injection Pad #3. a yr �'r�s�-Y, r�' �, 3 ca (o
